(220 ILCS 5/Art. I heading) ARTICLE I. TITLE AND PURPOSE

(220 ILCS 5/1-101) (from Ch. 111 2/3, par. 1-101)

Sec. 1-101. Short title. This Act may be cited as the Public Utilities Act.

(Source: P.A. 86-1475.)

(220 ILCS 5/1-102) (from Ch. 111 2/3, par. 1-102)

Sec. 1-102. Findings and Intent. The General Assembly finds that the health, welfare and prosperity of all Illinois citizens require the provision of adequate, efficient, reliable, environmentally safe and least-cost public utility services at prices which accurately reflect the long-term cost of such services and which are equitable to all citizens. It is therefore declared to be the policy of the State that public utilities shall continue to be regulated effectively and comprehensively. It is further declared that the goals and objectives of such regulation shall be to ensure

(a) Efficiency: the provision of reliable energy services at the least possible cost to the citizens of the State; in such manner that:

(i) physical, human and financial resources are allocated efficiently;

(ii) all supply and demand options are considered and evaluated using comparable terms and methods in order to determine how utilities shall meet their customers' demands for public utility services at the least cost;

(iii) utilities are allowed a sufficient return on investment so as to enable them to attract capital in financial markets at competitive rates;

(iv) tariff rates for the sale of various public utility services are authorized such that they accurately reflect the cost of delivering those services and allow utilities to recover the total costs prudently and reasonably incurred;

(v) variation in costs by customer class and time of use is taken into consideration in authorizing rates for each class.

(b) Environmental Quality: the protection of the environment from the adverse external costs of public utility services so that

(i) environmental costs of proposed actions having a significant impact on the environment and the environmental impact of the alternatives are identified, documented and considered in the regulatory process;

(ii) the prudently and reasonably incurred costs of environmental controls are recovered.

(c) Reliability: the ability of utilities to provide consumers with public utility services under varying demand conditions in such manner that suppliers of public utility services are able to provide service at varying levels of economic reliability giving appropriate consideration to the costs likely to be incurred as a result of service interruptions, and to the costs of increasing or maintaining current levels of reliability consistent with commitments to consumers.

(d) Equity: the fair treatment of consumers and investors in order that

(i) the public health, safety and welfare shall be protected;

(ii) the application of rates is based on public understandability and acceptance of the reasonableness of the rate structure and level;

(iii) the cost of supplying public utility services is allocated to those who cause the costs to be incurred;

(iv) if factors other than cost of service are considered in regulatory decisions, the rationale for these actions is set forth;

(v) regulation allows for orderly transition periods to accommodate changes in public utility service markets;

(vi) regulation does not result in undue or sustained adverse impact on utility earnings;

(vii) the impacts of regulatory actions on all sectors of the State are carefully weighed;

(viii) the rates for utility services are affordable and therefore preserve the availability of such services to all citizens.

It is further declared to be the policy of the State that this Act shall not apply in relation to motor carriers and rail carriers as defined in the Illinois Commercial Transportation Law, or to the Commission in the regulation of such carriers.

Nothing in this Act shall be construed to limit, restrict, or mitigate in any way the power and authority of the State's Attorneys or the Attorney General under the Consumer Fraud and Deceptive Business Practices Act.

(Source: P.A. 92-22, eff. 6-30-01.)

(220 ILCS 5/Art. II heading) ARTICLE II. ILLINOIS COMMERCE COMMISSION

(220 ILCS 5/2-101) (from Ch. 111 2/3, par. 2-101)

Sec. 2-101. Commerce Commission created. There is created an Illinois Commerce Commission consisting of 5 members not more than 3 of whom shall be members of the same political party at the time of appointment. The Governor shall appoint the members of such Commission by and with the advice and consent of the Senate. In case of a vacancy in such office during the recess of the Senate the Governor shall make a temporary appointment until the next meeting of the Senate, when he shall nominate some person to fill such office; and any person so nominated who is confirmed by the Senate, shall hold his office during the remainder of the term and until his successor shall be appointed and qualified. Each member of the Commission shall hold office for a term of 5 years from the third Monday in January of the year in which his predecessor's term expires.

Notwithstanding any provision of this Section to the contrary, the term of office of each member of the Commission is terminated on the effective date of this amendatory Act of 1995, but the incumbent members shall continue to exercise all of the powers and be subject to all of the duties of members of the Commission until their respective successors are appointed and qualified. Of the members initially appointed under the provisions of this amendatory Act of 1995, one member shall be appointed for a term of office which shall expire on the third Monday of January, 1997; 2 members shall be appointed for terms of office which shall expire on the third Monday of January, 1998; one member shall be appointed for a term of office which shall expire on the third Monday of January, 1999; and one member shall be appointed for a term of office which shall expire on the third Monday of January, 2000. Each respective successor shall be appointed for a term of 5 years from the third Monday of January of the year in which his predecessor's term expires in accordance with the provisions of the first paragraph of this Section.

Each member shall serve until his successor is appointed and qualified, except that if the Senate refuses to consent to the appointment of any member, such office shall be deemed vacant, and within 2 weeks of the date the Senate refuses to consent to the reappointment of any member, such member shall vacate such office. The Governor shall from time to time designate the member of the Commission who shall be its chairman. Consistent with the provisions of this Act, the Chairman shall be the chief executive officer of the Commission for the purpose of ensuring that the Commission's policies are properly executed.

If there is no vacancy on the Commission, 4 members of the Commission shall constitute a quorum to transact business; otherwise, a majority of the Commission shall constitute a quorum to transact business, and no vacancy shall impair the right of the remaining commissioners to exercise all of the powers of the Commission. Every finding, order, or decision approved by a majority of the members of the Commission shall be deemed to be the finding, order, or decision of the Commission.

(Source: P.A. 92-22, eff. 6-30-01.)

(220 ILCS 5/2-102) (from Ch. 111 2/3, par. 2-102)

Sec. 2-102. (a) Each commissioner and each person appointed to office by the Commission shall before entering upon the duties of his office take and subscribe the constitutional oath of office.

Before entering upon the duties of his office each commissioner shall give bond, with security to be approved by the Governor, in the sum of $20,000, conditioned for the faithful performance of his duty as such commissioner. Every person appointed or employed by the Commission, may, in the discretion of the Commission, before entering upon the duties of his office, be required to give bond for the faithful discharge of his duties, in such sum as the Commission may designate, which bond shall be approved by the Commission.

All bonds required to be filed pursuant to this section shall be filed in the office of the Secretary of State.

(b) No person in the employ of or holding any official relation to any corporation or person subject in whole or in part to regulation by the Commission, and no person holding stock or bonds in any such corporation, or who is in any other manner pecuniarily interested therein, directly or indirectly, shall be appointed to or hold the office of commissioner or be appointed or employed by the Commission; and if any such person shall voluntarily become so interested his office or employment shall ipso facto become vacant. If any person become so interested otherwise than voluntarily he shall within a reasonable time divest himself of such interest, and if he fails to do so his office or employment shall become vacant.

No commissioner or person appointed or employed by the Commission shall solicit or accept any gift, gratuity, emolument or employment from any person or corporation subject to the supervision of the Commission, or from any officer, agent or employee thereof; nor solicit, request from or recommend, directly or indirectly, to any such person or corporation, or to any officer, agent or employee thereof the appointment of any person to any place or position. Every such corporation and person, and every officer, agent or employee thereof, is hereby forbidden to offer to any commissioner or to any person appointed or employed by the Commission any gift, gratuity, emolument or employment. If any commissioner or any person appointed or employed by the Commission shall violate any provisions of this paragraph he shall be removed from the office or employment held by him. Every person violating the provisions of this paragraph shall be guilty of a Class A misdemeanor.

(c) Each commissioner shall devote his entire time to the duties of his office, and shall hold no other office or position of profit, or engage in any other business, employment or vocation.

(Source: P.A. 84-617.)

(220 ILCS 5/2-103) (from Ch. 111 2/3, par. 2-103)

Sec. 2-103. (a) No former member of the Commission or person formerly employed by the Commission may represent any person before the Commission in any capacity with respect to any particular Commission proceeding in which he participated personally and substantially as a member or employee of the Commission.

(b) No former member of the Commission may appear before the Commission in connection with any Commission proceeding for a period of 2 years following the termination of service with the Commission.

(c) No former member of the Commission may accept any employment with any entity subject to Commission regulation or certification, or with any industry trade association that (i) receives a majority of its funding from entities regulated or certificated by the Commission; or (ii) has a majority of members regulated or certificated by the Commission, for one year following the termination of services with the Commission; provided such prohibition shall extend to 2 years for commissioners appointed subsequent to the effective date of this amendatory Act of the 96th General Assembly.

(d) No entity subject to Commission regulation or certification or any industry trade association that (i) receives a majority of its funding from entities regulated or certificated by the Commission; or (ii) has a majority of members regulated or certificated by the Commission shall offer a former member of the Commission employment for a period of one year following the termination of the former Commission member's service with the Commission, or otherwise hire such person as an agent, consultant, or attorney where such employment or contractual relation would be in violation of this Section; provided such prohibition on offers of employment shall extend to 2 years for those commissioners appointed subsequent to the effective date of this amendatory Act of the 96th General Assembly.

(Source: P.A. 96-33, eff. 7-10-09.)

(220 ILCS 5/2-104) (from Ch. 111 2/3, par. 2-104)

Sec. 2-104. It is declared to be the public policy of this State that the Illinois Commerce Commission established herein is a quasi-judicial body and that each commissioner shall receive an annual salary of $39,000, or such amount as set by the Compensation Review Board, whichever is greater. The chairman of the Commission shall receive in addition to his salary as a commissioner an additional sum of $8,500 per year, or an amount set by the Compensation Review Board, whichever is greater, during such time as he shall serve as chairman.

(Source: P.A. 84-617.)

(220 ILCS 5/2-105) (from Ch. 111 2/3, par. 2-105)

Sec. 2-105. Organization; executive director; assistants to Commissioners.

(a) In order that the Commission may perform the duties and exercise the powers granted to it and assume its responsibilities under this Act and any and all other statutes of this State, the Commission, acting jointly, shall hire an executive director who shall be responsible to the Commission and shall serve subject only to removal by the Commission for good cause. The executive director shall be responsible for the supervision and direction of the Commission staff and for the necessary administrative activities of the Commission, subject only to Commission direction and approval. In furtherance thereof, the executive director may organize the Commission staff into such departments, bureaus, sections, or divisions as he may deem necessary or appropriate. In connection therewith, the executive director may delegate and assign to one or more staff member or members the supervision and direction of any such department, bureau, section, or division.

(b) The executive director shall obtain, subject to the provisions of the Personnel Code, such accountants, engineers, experts, inspectors, clerks, and employees as may be necessary to carry out the provisions of this Act or to perform the duties and exercise the powers conferred by law upon the Commission. All accountants, engineers, experts, inspectors, clerks, and employees of the Commission shall receive the compensation fixed by the Executive Director, subject only to Commission approval. Notwithstanding these provisions, each commissioner shall have the authority to retain up to 2 full-time assistants, subject to the provisions of the Personnel Code, who shall be supervised by the commissioner and whose compensation shall be fixed by the commissioner.

(c) The commissioners, executive director, administrative law judges, accountants, engineers, clerks, inspectors, experts, and other employees shall have reimbursed to them all actual and necessary traveling and other expenses and disbursements necessarily incurred or made by them in the discharge of their official duties. The Commission and executive director may also incur necessary expenses for office furniture, stationery, printing, and other incidental expenses.

(d) A copy of any contract executed between the Commission and the executive director which establishes or provides for the expenditure of public funds shall be filed with the State Comptroller within 15 days of execution and shall be available for public inspection. Any cancellation or modification of any such contract shall be filed with the State Comptroller within 15 days of execution and shall be available for public inspection. When a contract or modification required to be filed under this subsection has not been filed within 30 days of execution, the State Comptroller shall refuse to issue any warrant for payment thereunder until the Commission files the contract or modification with the State Comptroller.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/2-106) (from Ch. 111 2/3, par. 2-106)

Sec. 2-106. (a) The executive director shall employ administrative law judges to make valuations of public utility properties, or to estimate proper rates of service of public utilities, or to examine other questions coming before the Commission, by taking testimony or by independent investigation. The executive director shall designate one administrative law judge to serve as chief administrative law judge who shall be responsible for supervising and directing the activities of all administrative law judges, subject to the approval of the executive director. Administrative law judges shall, under the direction of the chief administrative law judge, take testimony of witnesses, examine accounts, records, books, papers and physical properties, either by holding hearings or making independent investigations, in any matter referred to them by the chief administrative law judge; and make report thereof to the chief administrative law judge, and attend at hearings before the Commission when so directed by the chief administrative law judge, for the purpose of explaining their investigations and the result thereof to the Commission and the parties interested; and perform such other duties as the chief administrative law judge may direct.

(b) All administrative law judges employed by the Commission shall be thoroughly familiar with applicable rules of evidence, procedure and administrative law. At least every two years after an administrative law judge is employed by the Commission, the executive director and chief administrative law judge shall review the performance of such administrative law judge based on whether the administrative law judge:

(i) is, and is perceived to be, fair to all parties;

(ii) has a judicious and considerate temperament;

(iii) is capable of comprehending and properly conducting proceedings and other duties to which he is assigned;

(iv) is capable of understanding and rendering rulings on legal and evidentiary issues;

(v) is capable of independently evaluating the evidentiary record and drafting a proposed final order which reflects careful, impartial and competent analysis; and

(vi) meets any other qualifications deemed relevant or necessary by the executive director or chief administrative law judge.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/2-107) (from Ch. 111 2/3, par. 2-107)

Sec. 2-107. The office of the Commission shall be in Springfield, but the Commission may, with the approval of the Governor, establish and maintain branch offices at places other than the seat of government. Such office shall be open for business between the hours of 8:30 a.m. and 5:00 p.m. throughout the year, and one or more responsible persons to be designated by the executive director shall be on duty at all times in immediate charge thereof.

The Commission shall hold stated meetings at least once a month and may hold such special meetings as it may deem necessary at any place within the State. At each regular and special meeting that is open to the public, members of the public shall be afforded time, subject to reasonable constraints, to make comments to or to ask questions of the Commission.

The Commission shall provide a web site and a toll-free telephone number to accept comments from Illinois residents regarding any matter under the auspices of the Commission or before the Commission. The Commission staff shall report, in a manner established by the Commission that is consistent with the Commission's rules regarding ex parte communications, to the full Commission comments and suggestions received through both venues before all relevant votes of the Commission.

The Commission may, for the authentication of its records, process and proceedings, adopt, keep and use a common seal, of which seal judicial notice shall be taken in all courts of this State; and any process, notice, order or other paper which the Commission may be authorized by law to issue shall be deemed sufficient if signed and certified by the Chairman of the Commission or his or her designee, either by hand or by facsimile, and with such seal attached; and all acts, orders, proceedings, rules, entries, minutes, schedules and records of the Commission, and all reports and documents filed with the Commission, may be proved in any court of this State by a copy thereof, certified to by the Chairman of the Commission, with the seal of the Commission attached.

Notwithstanding any other provision of this Section, the Commission's established procedures for accepting testimony from Illinois residents on matters pending before the Commission shall be consistent with the Commission's rules regarding ex parte communications and due process.

(Source: P.A. 95-127, eff. 8-13-07.)

(220 ILCS 5/2-108) (from Ch. 111 2/3, par. 2-108)

Sec. 2-108. Disqualification of a Commissioner from certain proceedings.

(a) Definitions. In this Section:

"Degree of relationship" is calculated according to the civil law.

"Fiduciary" includes without limitation a personal representative, an executor, an administrator, a trustee, and a guardian.

"Financial interest" means ownership of a legal or equitable interest, however small, or being in the relationship of director, advisor, or other active participant in the affairs of a party, except the following:

(i) Ownership in a mutual or common investment fund that holds securities is not a "financial interest" in those securities unless the Commissioner participates in the management of the fund.

(ii) An office in an educational, religious, charitable, fraternal, or civic organization is not a "financial interest" in securities held by the organization.

(iii) The proprietary interest of a policyholder in a mutual insurance company, a depositor in a mutual savings association, or a similar proprietary interest is a "financial interest" in the organization only if the outcome of the proceeding could substantially affect the value of the interest.

(iv) Ownership of government securities is a "financial interest" in the issuer only if the outcome of the proceeding could substantially affect the value of the securities.

(b) A Commissioner must disqualify himself or herself in a proceeding in which his or her impartiality might reasonably be questioned, including without limitation the following:

(1) The Commissioner has a personal bias or prejudice concerning a party or a party's lawyer.

(2) At any time during the preceding 3 years, the Commissioner was employed by or served as a lawyer, witness, consultant, or advisor, with respect to any regulatory issue within the purview of the statutes conferring jurisdiction on the Commission for any public utility, telecommunications carrier, motor carrier, or an affiliated interest of a public utility, telecommunications carrier, or motor carrier who is a party to the proceeding.

(3) The Commissioner was, within the preceding 3 years, a partner in, associated with, or employed by any firm, partnership, company, or corporation which, within the preceding 3 years or currently, served or is serving as a lawyer, witness, consultant, or advisor, with respect to any regulatory issue within the purview of the statutes conferring jurisdiction on the Commission for any public utility, telecommunications carrier, motor carrier, or an affiliated interest of a public utility, telecommunications carrier, or motor carrier who is a party to the proceeding, except that referral of cases when no monetary interest is retained is not an association within the meaning of this paragraph.

(4) The Commissioner knows that he or she, individually or as a fiduciary, or that a spouse or minor child residing in his or her household has a substantial financial interest in the subject matter of the proceeding or in a party to the proceeding or has any interest other than financial that could be substantially affected by the outcome of the proceeding.

(5) The Commissioner, his or her spouse, a person within the second degree of relationship to either of them, or the spouse of a person within that degree of relationship:

(A) is a party to the proceeding or an officer, director, or trustee of a party;

(B) is acting as a lawyer in the proceeding; or

(C) is to the Commissioner's knowledge likely to be a witness, consultant, or advisor to any party to the proceeding.

(c) A Commissioner must inform himself or herself about the Commissioner's personal and fiduciary financial interests and shall make a reasonable effort to inform himself or herself about the personal financial interests of the Commissioner's spouse and minor children residing in his or her household.

(d) If a Commissioner disqualifies himself or herself, the Commissioner shall provide a written explanation of the reasons for the disqualification to all parties to the proceeding.

This Section shall apply only to persons appointed or reappointed to the Illinois Commerce Commission and confirmed by the Senate after the effective date of this amendatory Act of 1991.

(Source: P.A. 87-801.)

(220 ILCS 5/2-201) (from Ch. 111 2/3, par. 2-201)

Sec. 2-201. There shall be paid to the Commission the following fees: For copies of evidence and proceedings before the Commission, official documents and orders filed in its office, or other papers and records, whether or not certified or otherwise authenticated, 25¢ for each folio, and $1 for each certificate with a seal affixed thereto.

For certifying each copy of the Commission's annual report, or each copy of any report made by a public utility to the Commission, $1.

No fees shall be charged or collected for copies of papers, records, or official documents furnished to any city or public officers, including the Public Counsel, for use in their official capacity, or for the annual reports of the Commission in the ordinary course of distribution, but the Commission may fix reasonable charges for publications issued under its authority. All fees charged and collected by the Commission shall be paid promptly after the receipt of the same, accompanied by a detailed statement thereof, into the Public Utility Fund in the State treasury.

(Source: P.A. 84-617; 84-1118.)

(220 ILCS 5/2-202) (from Ch. 111 2/3, par. 2-202)

Sec. 2-202. Policy; Public Utility Fund; tax.

(a) It is declared to be the public policy of this State that in order to maintain and foster the effective regulation of public utilities under this Act in the interests of the People of the State of Illinois and the public utilities as well, the public utilities subject to regulation under this Act and which enjoy the privilege of operating as public utilities in this State, shall bear the expense of administering this Act by means of a tax on such privilege measured by the annual gross revenue of such public utilities in the manner provided in this Section. For purposes of this Section, "expense of administering this Act" includes any costs incident to studies, whether made by the Commission or under contract entered into by the Commission, concerning environmental pollution problems caused or contributed to by public utilities and the means for eliminating or abating those problems. Such proceeds shall be deposited in the Public Utility Fund in the State treasury.

(b) All of the ordinary and contingent expenses of the Commission incident to the administration of this Act shall be paid out of the Public Utility Fund except the compensation of the members of the Commission which shall be paid from the General Revenue Fund. Notwithstanding other provisions of this Act to the contrary, the ordinary and contingent expenses of the Commission incident to the administration of the Illinois Commercial Transportation Law may be paid from appropriations from the Public Utility Fund through the end of fiscal year 1986.

(c) A tax is imposed upon each public utility subject to the provisions of this Act equal to .08% of its gross revenue for each calendar year commencing with the calendar year beginning January 1, 1982, except that the Commission may, by rule, establish a different rate no greater than 0.1%. For purposes of this Section, "gross revenue" shall not include revenue from the production, transmission, distribution, sale, delivery, or furnishing of electricity. "Gross revenue" shall not include amounts paid by telecommunications retailers under the Telecommunications Infrastructure Maintenance Fee Act.

(d) Annual gross revenue returns shall be filed in accordance with paragraph (1) or (2) of this subsection (d).

(1) Except as provided in paragraph (2) of this subsection (d), on or before January 10 of each year each public utility subject to the provisions of this Act shall file with the Commission an estimated annual gross revenue return containing an estimate of the amount of its gross revenue for the calendar year commencing January 1 of said year and a statement of the amount of tax due for said calendar year on the basis of that estimate. Public utilities may also file revised returns containing updated estimates and updated amounts of tax due during the calendar year. These revised returns, if filed, shall form the basis for quarterly payments due during the remainder of the calendar year. In addition, on or before March 31 of each year, each public utility shall file an amended return showing the actual amount of gross revenues shown by the company's books and records as of December 31 of the previous year. Forms and instructions for such estimated, revised, and amended returns shall be devised and supplied by the Commission.

(2) Beginning with returns due after January 1, 2002, the requirements of paragraph (1) of this subsection (d) shall not apply to any public utility in any calendar year for which the total tax the public utility owes under this Section is less than $10,000. For such public utilities with respect to such years, the public utility shall file with the Commission, on or before March 31 of the following year, an annual gross revenue return for the year and a statement of the amount of tax due for that year on the basis of such a return. Forms and instructions for such returns and corrected returns shall be devised and supplied by the Commission.

(e) All returns submitted to the Commission by a public utility as provided in this subsection (e) or subsection (d) of this Section shall contain or be verified by a written declaration by an appropriate officer of the public utility that the return is made under the penalties of perjury. The Commission may audit each such return submitted and may, under the provisions of Section 5-101 of this Act, take such measures as are necessary to ascertain the correctness of the returns submitted. The Commission has the power to direct the filing of a corrected return by any utility which has filed an incorrect return and to direct the filing of a return by any utility which has failed to submit a return. A taxpayer's signing a fraudulent return under this Section is perjury, as defined in Section 32-2 of the Criminal Code of 2012.

(f)(1) For all public utilities subject to paragraph (1) of subsection (d), at least one quarter of the annual amount of tax due under subsection (c) shall be paid to the Commission on or before the tenth day of January, April, July, and October of the calendar year subject to tax. In the event that an adjustment in the amount of tax due should be necessary as a result of the filing of an amended or corrected return under subsection (d) or subsection (e) of this Section, the amount of any deficiency shall be paid by the public utility together with the amended or corrected return and the amount of any excess shall, after the filing of a claim for credit by the public utility, be returned to the public utility in the form of a credit memorandum in the amount of such excess or be refunded to the public utility in accordance with the provisions of subsection (k) of this Section. However, if such deficiency or excess is less than $1, then the public utility need not pay the deficiency and may not claim a credit.

(2) Any public utility subject to paragraph (2) of subsection (d) shall pay the amount of tax due under subsection (c) on or before March 31 next following the end of the calendar year subject to tax. In the event that an adjustment in the amount of tax due should be necessary as a result of the filing of a corrected return under subsection (e), the amount of any deficiency shall be paid by the public utility at the time the corrected return is filed. Any excess tax payment by the public utility shall be returned to it after the filing of a claim for credit, in the form of a credit memorandum in the amount of the excess. However, if such deficiency or excess is less than $1, the public utility need not pay the deficiency and may not claim a credit.

(g) Each installment or required payment of the tax imposed by subsection (c) becomes delinquent at midnight of the date that it is due. Failure to make a payment as required by this Section shall result in the imposition of a late payment penalty, an underestimation penalty, or both, as provided by this subsection. The late payment penalty shall be the greater of:

(1) $25 for each month or portion of a month that the installment or required payment is unpaid or

(2) an amount equal to the difference between what should have been paid on the due date, based upon the most recently filed estimated, annual, or amended return, and what was actually paid, times 1%, for each month or portion of a month that the installment or required payment goes unpaid. This penalty may be assessed as soon as the installment or required payment becomes delinquent.

The underestimation penalty shall apply to those public utilities subject to paragraph (1) of subsection (d) and shall be calculated after the filing of the amended return. It shall be imposed if the amount actually paid on any of the dates specified in subsection (f) is not equal to at least one-fourth of the amount actually due for the year, and shall equal the greater of:

(1) $25 for each month or portion of a month that the amount due is unpaid or

(2) an amount equal to the difference between what should have been paid, based on the amended return, and what was actually paid as of the date specified in subsection (f), times a percentage equal to 1/12 of the sum of 10% and the percentage most recently established by the Commission for interest to be paid on customer deposits under 83 Ill. Adm. Code 280.70(e)(1), for each month or portion of a month that the amount due goes unpaid, except that no underestimation penalty shall be assessed if the amount actually paid on or before each of the dates specified in subsection (f) was based on an estimate of gross revenues at least equal to the actual gross revenues for the previous year. The Commission may enforce the collection of any delinquent installment or payment, or portion thereof by legal action or in any other manner by which the collection of debts due the State of Illinois may be enforced under the laws of this State. The executive director or his designee may excuse the payment of an assessed penalty or a portion of an assessed penalty if he determines that enforced collection of the penalty as assessed would be unjust.

(h) All sums collected by the Commission under the provisions of this Section shall be paid promptly after the receipt of the same, accompanied by a detailed statement thereof, into the Public Utility Fund in the State treasury.

(i) During the month of October of each odd-numbered year the Commission shall:

(1) determine the amount of all moneys deposited in the Public Utility Fund during the preceding fiscal biennium plus the balance, if any, in that fund at the beginning of that biennium;

(2) determine the sum total of the following items: (A) all moneys expended or obligated against appropriations made from the Public Utility Fund during the preceding fiscal biennium, plus (B) the sum of the credit memoranda then outstanding against the Public Utility Fund, if any; and

(3) determine the amount, if any, by which the sum determined as provided in item (1) exceeds the amount determined as provided in item (2).

If the amount determined as provided in item (3) of this subsection exceeds 50% of the previous fiscal year's appropriation level, the Commission shall then compute the proportionate amount, if any, which (x) the tax paid hereunder by each utility during the preceding biennium, and (y) the amount paid into the Public Utility Fund during the preceding biennium by the Department of Revenue pursuant to Sections 2-9 and 2-11 of the Electricity Excise Tax Law, bears to the difference between the amount determined as provided in item (3) of this subsection (i) and 50% of the previous fiscal year's appropriation level. The Commission shall cause the proportionate amount determined with respect to payments made under the Electricity Excise Tax Law to be transferred into the General Revenue Fund in the State Treasury, and notify each public utility that it may file during the 3 month period after the date of notification a claim for credit for the proportionate amount determined with respect to payments made hereunder by the public utility. If the proportionate amount is less than $10, no notification will be sent by the Commission, and no right to a claim exists as to that amount. Upon the filing of a claim for credit within the period provided, the Commission shall issue a credit memorandum in such amount to such public utility. Any claim for credit filed after the period provided for in this Section is void.

(i-5) During the month of June of each year the Commission shall:

(1) determine the amount of all moneys expected to be deposited in the Public Utility Fund during the next fiscal year, plus the balance, if any, in that fund at the beginning of that year;

(2) determine the total of all moneys expected to be expended or obligated against appropriations made from the Public Utility Fund during the next fiscal year; and

(3) determine the amount, if any, by which the amount determined in paragraph (2) exceeds the amount determined as provided in paragraph (1).

If the amount determined as provided in paragraph (3) of this subsection (i-5) results in a deficit, the Commission may assess electric utilities and gas utilities for the difference between the amount appropriated for the ordinary and contingent expenses of the Commission and the amount derived under paragraph (1) of this subsection (i-5). Such proceeds shall be deposited in the Public Utility Fund in the State treasury. The Commission shall apportion that difference among those public utilities on the basis of each utility's share of the total intrastate gross revenues of the utilities subject to this subsection (i-5). Payments required under this subsection (i-5) shall be made in the time and manner directed by the Commission. The Commission shall permit utilities to recover Illinois Commerce Commission assessments effective pursuant to this subsection through an automatic adjustment mechanism that is incorporated into an existing tariff that recovers costs associated with this Section, or through a supplemental customer charge.

Within 6 months after the first time assessments are made under this subsection (i-5), the Commission shall initiate a docketed proceeding in which it shall consider, in addition to assessments from electric and gas utilities subject to this subsection, the raising of assessments from, or the payment of fees by, water and sewer utilities, entities possessing certificates of service authority as alternative retail electric suppliers under Section 16-115 of this Act, entities possessing certificates of service authority as alternative gas suppliers under Section 19-110 of this Act, and telecommunications carriers providing local exchange telecommunications service or interexchange telecommunications service under Sections 13-204 or 13-205 of this Act. The amounts so determined shall be based on the costs to the agency of the exercise of its regulatory and supervisory functions with regard to the different industries and service providers subject to the proceeding. No less often than every 3 years after the end of a proceeding under this subsection (i-5), the Commission shall initiate another proceeding for that purpose.

The Commission may use this apportionment method until the docketed proceeding in which the Commission considers the raising of assessments from other entities subject to its jurisdiction under this Act has concluded. No credit memoranda shall be issued pursuant to subsection (i) if the amount determined as provided in paragraph (3) of this subsection (i-5) results in a deficit.

(j) Credit memoranda issued pursuant to subsection (f) and credit memoranda issued after notification and filing pursuant to subsection (i) may be applied for the 2 year period from the date of issuance, against the payment of any amount due during that period under the tax imposed by subsection (c), or, subject to reasonable rule of the Commission including requirement of notification, may be assigned to any other public utility subject to regulation under this Act. Any application of credit memoranda after the period provided for in this Section is void.

(k) The chairman or executive director may make refund of fees, taxes or other charges whenever he shall determine that the person or public utility will not be liable for payment of such fees, taxes or charges during the next 24 months and he determines that the issuance of a credit memorandum would be unjust.

(Source: P.A. 102-931, eff. 5-27-22.)

(220 ILCS 5/2-203)

Sec. 2-203. (Repealed).

(Source: P.A. 98-602, eff. 12-6-13. Repealed internally, eff. 4-1-15.)

(220 ILCS 5/Art. III heading) ARTICLE III. DEFINITIONS

(220 ILCS 5/3-101) (from Ch. 111 2/3, par. 3-101)

Sec. 3-101. Definitions. Unless otherwise specified, the terms set forth in Sections 3-102 through 3-126 are used in this Act as therein defined.

(Source: P.A. 97-96, eff. 7-13-11; 97-239, eff. 8-2-11; 97-813, eff. 7-13-12.)

(220 ILCS 5/3-102) (from Ch. 111 2/3, par. 3-102)

Sec. 3-102. "Commission" means the Illinois Commerce Commission, which is created and established under the provisions of this Act.

(Source: P.A. 84-617.)

(220 ILCS 5/3-103) (from Ch. 111 2/3, par. 3-103)

Sec. 3-103. "Commissioner" means one of the members of the Commission.

(Source: P.A. 84-617.)

(220 ILCS 5/3-104) (from Ch. 111 2/3, par. 3-104)

Sec. 3-104. "Executive Director" means the person holding the position of Executive Director created and established under the provisions of this Act.

(Source: P.A. 84-617.)

(220 ILCS 5/3-105) (from Ch. 111 2/3, par. 3-105)

Sec. 3-105. Public utility.

(a) "Public utility" means and includes, except where otherwise expressly provided in this Section, every corporation, company, limited liability company, association, joint stock company or association, firm, partnership or individual, their lessees, trustees, or receivers appointed by any court whatsoever that owns, controls, operates or manages, within this State, directly or indirectly, for public use, any plant, equipment or property used or to be used for or in connection with, or owns or controls any franchise, license, permit or right to engage in:

(1) the production, storage, transmission, sale, delivery or furnishing of heat, cold, power, electricity, water, or light, except when used solely for communications purposes;

(2) the disposal of sewerage; or

(3) the conveyance of oil or gas by pipe line.

(b) "Public utility" does not include, however:

(1) public utilities that are owned and operated by any political subdivision, public institution of higher education or municipal corporation of this State, or public utilities that are owned by such political subdivision, public institution of higher education, or municipal corporation and operated by any of its lessees or operating agents;

(2) water companies which are purely mutual concerns, having no rates or charges for services, but paying the operating expenses by assessment upon the members of such a company and no other person;

(3) electric cooperatives as defined in Section 3-119;

(4) the following natural gas cooperatives:

(A) residential natural gas cooperatives that are not-for-profit corporations established for the purpose of administering and operating, on a cooperative basis, the furnishing of natural gas to residences for the benefit of their members who are residential consumers of natural gas. For entities qualifying as residential natural gas cooperatives and recognized by the Illinois Commerce Commission as such, the State shall guarantee legally binding contracts entered into by residential natural gas cooperatives for the express purpose of acquiring natural gas supplies for their members. The Illinois Commerce Commission shall establish rules and regulations providing for such guarantees. The total liability of the State in providing all such guarantees shall not at any time exceed $1,000,000, nor shall the State provide such a guarantee to a residential natural gas cooperative for more than 3 consecutive years; and

(B) natural gas cooperatives that are not-for-profit corporations operated for the purpose of administering, on a cooperative basis, the furnishing of natural gas for the benefit of their members and that, prior to 90 days after the effective date of this amendatory Act of the 94th General Assembly, either had acquired or had entered into an asset purchase agreement to acquire all or substantially all of the operating assets of a public utility or natural gas cooperative with the intention of operating those assets as a natural gas cooperative;

(5) sewage disposal companies which provide sewage disposal services on a mutual basis without establishing rates or charges for services, but paying the operating expenses by assessment upon the members of the company and no others;

(6) (blank);

(7) cogeneration facilities, small power production facilities, and other qualifying facilities, as defined in the Public Utility Regulatory Policies Act and regulations promulgated thereunder, except to the extent State regulatory jurisdiction and action is required or authorized by federal law, regulations, regulatory decisions or the decisions of federal or State courts of competent jurisdiction;

(8) the ownership or operation of a facility that sells compressed natural gas at retail to the public for use only as a motor vehicle fuel and the selling of compressed natural gas at retail to the public for use only as a motor vehicle fuel;

(9) alternative retail electric suppliers as defined in Article XVI; and

(10) the Illinois Power Agency.

(c) An entity that furnishes the service of charging electric vehicles does not and shall not be deemed to sell electricity and is not and shall not be deemed a public utility notwithstanding the basis on which the service is provided or billed. If, however, the entity is otherwise deemed a public utility under this Act, or is otherwise subject to regulation under this Act, then that entity is not exempt from and remains subject to the otherwise applicable provisions of this Act. The installation, maintenance, and repair of an electric vehicle charging station shall comply with the requirements of subsection (a) of Section 16-128 and Section 16-128A of this Act.

For purposes of this subsection, the term "electric vehicles" has the meaning ascribed to that term in Section 10 of the Electric Vehicle Act.

(Source: P.A. 97-1128, eff. 8-28-12.)

(220 ILCS 5/3-112) (from Ch. 111 2/3, par. 3-112)

Sec. 3-112. "Company," when used in connection with a public utility, includes any corporation, company, limited liability company, association, joint stock company or association, firm, partnership or individual, their lessees, trustees, or receivers appointed by any court whatsoever, owning, holding, operating, controlling or managing such a public utility, but not municipal corporations. "Company" when used other than in connection with a public utility, includes any corporation, company, limited liability company, association, joint stock company or association, firm or partnership, but does not include municipal corporations.

(Source: P.A. 88-480.)

(220 ILCS 5/3-113) (from Ch. 111 2/3, par. 3-113)

Sec. 3-113. "Corporation" includes any corporation, company, limited liability company, association, joint stock company or association, but not municipal corporations.

(Source: P.A. 88-480.)

(220 ILCS 5/3-114) (from Ch. 111 2/3, par. 3-114)

Sec. 3-114. "Person" includes an individual, firm, limited liability company, or co-partnership.

(Source: P.A. 88-480.)

(220 ILCS 5/3-115) (from Ch. 111 2/3, par. 3-115)

Sec. 3-115. "Service" is used in its broadest and most inclusive sense, and includes not only the use or accommodation afforded consumers or patrons, but also any product or commodity furnished by any public utility and the plant, equipment, apparatus, appliances, property and facilities employed by, or in connection with, any public utility in performing any service or in furnishing any product or commodity and devoted to the purposes in which such public utility is engaged and to the use and accommodation of the public.

(Source: P.A. 84-617.)

(220 ILCS 5/3-116) (from Ch. 111 2/3, par. 3-116)

Sec. 3-116. "Rate" includes every individual or joint rate, fare, toll, charge, rental or other compensation of any public utility or any two or more such individual or joint rates, fares, tolls, charges, rental or other compensation of any public utility or any schedule or tariff thereof, and any rule, regulation, charge, practice or contract relating thereto.

(Source: P.A. 84-617.)

(220 ILCS 5/3-117) (from Ch. 111 2/3, par. 3-117)

Sec. 3-117. "City council" includes the mayor and commissioners of cities which have adopted the Commission form of municipal government and the council of all other cities and the president and board of trustees of villages and incorporated towns.

(Source: P.A. 84-617.)

(220 ILCS 5/3-118) (from Ch. 111 2/3, par. 3-118)

Sec. 3-118. "City" includes all villages and incorporated towns.

(Source: P.A. 84-617.)

(220 ILCS 5/3-119) (from Ch. 111 2/3, par. 3-119)

Sec. 3-119. "Electric cooperative" is any electric cooperative which is subject to the Electric Suppliers Act, enacted by the 74th General Assembly, and has the same meaning as is defined in Section 3.4 of that Act.

(Source: P.A. 84-617.)

(220 ILCS 5/3-120) (from Ch. 111 2/3, par. 3-120)

Sec. 3-120. As used in Section 3-121 of this Act, the term "intrastate public utility business" includes all that portion of the business of the public utilities designated in Section 3-105 of this Act and over which this Commission has jurisdiction under the provisions of this Act.

(Source: P.A. 84-617; 84-1118.)

(220 ILCS 5/3-121) (from Ch. 111 2/3, par. 3-121)

Sec. 3-121. As used in Section 2-202 of this Act, the term "gross revenue" includes all revenue which (1) is collected by a public utility subject to regulations under this Act (a) pursuant to the rates, other charges, and classifications which it is required to file under Section 9-102 of this Act and (b) pursuant to emergency rates as permitted by Section 9-104 of this Act, and (2) is derived from the intrastate public utility business of such a utility. Such term does not include revenue derived by such a public utility from the sale of public utility services, products or commodities to another public utility, to an electric cooperative, or to a natural gas cooperative for resale by such public utility, electric cooperative, or natural gas cooperative. "Gross revenue" shall not include any charges added to customers' bills pursuant to the provisions of Section 9-221, 9-221.1 and 9-222 of this Act or consideration received from business enterprises certified under Section 9-222.1 of this Act to the extent of such exemption and during the period in which the exemption is in effect.

(Source: P.A. 94-738, eff. 5-4-06.)

(220 ILCS 5/3-122)

Sec. 3-122. Electronic. "Electronic" includes electrical, digital, magnetic, optical, electromagnetic, or any other form of technology that entails capabilities similar to these technologies.

(Source: P.A. 91-341, eff. 7-29-99.)

(220 ILCS 5/3-123)

(Text of Section from P.A. 97-96)

Sec. 3-123. Clean coal SNG brownfield facility; sequester; SNG facility; sourcing agreement; substitute natural gas or SNG. As used in this Act:

"Clean coal SNG brownfield facility" shall have the same meaning as provided in Section 1-10 of the Illinois Power Agency Act.

"Sequester" shall have the same meaning as provided in Section 1-10 of the Illinois Power Agency Act.

"SNG facility" means a facility that produces substitute natural gas from feedstock that includes coal through a gasification process, including a clean coal facility, the clean coal SNG brownfield facility, and the facility described in subsection (h) of Section 9-220 of this Act.

"Sourcing agreement" means an agreement between the owner of a clean coal SNG brownfield facility and the gas utility that has the terms and conditions meeting the requirements of subsection (h-1) of Section 9-220 of this Act.

"Substitute natural gas" or "SNG" shall have the same meaning as provided in Section 1-10 of the Illinois Power Agency Act.

(Source: P.A. 97-96, eff. 7-13-11.)

(Text of Section from P.A. 97-239)

Sec. 3-123. Clean coal facility; clean coal SNG facility; sequester; SNG facility; substitute natural gas or SNG. As used in this Act:

"Clean coal facility" shall have the same meaning as provided in Section 1-10 of the Illinois Power Agency Act.

"Clean coal SNG facility" shall have the same meaning as provided in Section 1-10 of the Illinois Power Agency Act.

"Sequester" shall have the same meaning as provided in Section 1-10 of the Illinois Power Agency Act.

"SNG facility" means a facility that produces substitute natural gas from feedstock that includes coal through a gasification process, including a clean coal facility, and the clean coal SNG facility.

"Substitute natural gas" or "SNG" shall have the same meaning as provided in Section 1-10 of the Illinois Power Agency Act.

(Source: P.A. 97-239, eff. 8-2-11.)

(220 ILCS 5/3-124)

Sec. 3-124. Adjusted final capitalized plant cost. "Adjusted final capitalized plant cost" means the final capitalized plant cost reduced by the following, without duplication and to the extent not already accounted for or reflected on the books of the facility: (1) any State of Illinois financial assistance, (2) any U.S. financial assistance, and (3) any quantifiable benefit from a U.S. Clean Coal Gasification Program received by the facility during a period equal to the shorter of (A) the life of such program or (B) the term of the agreement, such quantifiable benefit to be discounted at a rate of 14% per annum over such period.

(Source: P.A. 97-239, eff. 8-2-11.)

(220 ILCS 5/3-125)

Sec. 3-125. Final capitalized plant cost. "Final capitalized plant cost" means the total capitalized asset cost of the plant of the clean coal SNG facility as reflected on the balance sheet of the facility at the time of the commercial production date, with such capitalized cost to be accrued in accordance with generally accepted accounting principles, and includes, without limitation, the following items: major equipment, the SNG pipeline from the plant to the receiving pipeline, water lines, railroad improvements, access road improvements, all coal transportation assets, including the slurry line, slurry prep plant, carbon dioxide capture metering and compression, licensing fees, all costs incurred in the management planning, oversight and execution of the construction and start-up of the plant, and all fees and costs payable under engineering, procurement, and design contracts for the construct of the plant accrued as of the time of the commercial production date, but does not include capitalized financing costs including capitalized interest during construction and all fees associated with financing, coal reserve leasing costs, marketing, training, any and all costs payable under the contract miner agreement, the cost of coal mining equipment and similar costs, and any other costs, including general and administrative costs, not reasonably incurred in connection with the design, construction, testing, start-up, or commissioning of the plant in preparation for commercial production date.

(Source: P.A. 97-239, eff. 8-2-11.)

(220 ILCS 5/3-126)

Sec. 3-126. Total capitalized asset cost. "Total capitalized asset cost" means the gross book value of the plant, as determined in accordance with generally accepted accounting principles at the commercial production date.

(Source: P.A. 97-239, eff. 8-2-11.)

(220 ILCS 5/3-127)

Sec. 3-127. Carbon dioxide pipeline. "Carbon dioxide pipeline" has the same meaning given to that term in Section 10 of the Carbon Dioxide Transportation and Sequestration Act.

(Source: P.A. 103-651, eff. 7-18-24.)

(220 ILCS 5/Art. IV heading) ARTICLE IV. GENERAL POWERS AND DUTIES OF COMMISSION - INTERGOVERNMENTAL COOPERATION - CONSTRUCTION

(220 ILCS 5/4-101) (from Ch. 111 2/3, par. 4-101)

Sec. 4-101. The Commerce Commission shall have general supervision of all public utilities, except as otherwise provided in this Act, shall inquire into the management of the business thereof and shall keep itself informed as to the manner and method in which the business is conducted. It shall examine those public utilities and keep informed as to their general condition, their franchises, capitalization, rates and other charges, and the manner in which their plants, equipment and other property owned, leased, controlled or operated are managed, conducted and operated, not only with respect to the adequacy, security and accommodation afforded by their service but also with respect to their compliance with this Act and any other law, with the orders of the Commission and with the charter and franchise requirements.

Whenever the Commission is authorized or required by law to consider some aspect of criminal history record information for the purpose of carrying out its statutory powers and responsibilities, then, upon request and payment of fees in conformance with the requirements of Section 2605-400 of the Illinois State Police Law, the Illinois State Police is authorized to furnish, pursuant to positive identification, such information contained in State files as is necessary to fulfill the request.

The Commission shall require all public utilities to establish a security policy that includes on-site safeguards to restrict physical or electronic access to critical infrastructure and computerized control and data systems. The Commission shall maintain a record of and each regulated entity shall provide to the Commission an annual affidavit signed by a representative of the regulated entity that states:

(1) that the entity has a security policy in place;

(2) that the entity has conducted at least one practice exercise based on the security policy within the 12 months immediately preceding the date of the affidavit; and

(3) with respect to any entity that is an electric public utility, that the entity follows, at a minimum, the most current security standards set forth by the North American Electric Reliability Council.

(Source: P.A. 102-538, eff. 8-20-21.)

(220 ILCS 5/4-201) (from Ch. 111 2/3, par. 4-201)

Sec. 4-201. It is hereby made the duty of the Commission to see that the provisions of the Constitution and statutes of this State affecting public utilities, the enforcement of which is not specifically vested in some other officer or tribunal, are enforced and obeyed, and that violations thereof are promptly prosecuted and penalties due the State therefor recovered and collected, and to this end it may sue in the name of the People of the State.

It shall be the duty of the Commission, at the direction and discretion of the Chairman, to assemble and maintain an electronic trespass enforcement assistance staff consisting of experts in computer systems, electronics and other professional disciplines to aid public utilities, businesses, individuals and law enforcement agencies in detecting and preventing electronic trespass violations and enforcing the provisions of Sections 17-50, 17-51, and 17-52 of the Criminal Code of 2012 or any other relevant statute.

No cause of action shall exist and no liability may be imposed either civil or criminal, against the State, the Chairman of the Commission or any of its members, or any employee of the Commission, for any act or omission by them in the performance of any power or duty authorized by this Section, unless such act or omission was performed in bad faith and with intent to injure a particular person.

(Source: P.A. 97-1150, eff. 1-25-13.)

(220 ILCS 5/4-202) (from Ch. 111 2/3, par. 4-202)

Sec. 4-202. Action for injunction. Whenever the Commission shall be of the opinion that any public utility is failing or omitting or about to fail or omit to do anything required of it by law or by any order, decision, rule, regulation, direction, or requirement of the Commission, issued or made under authority of this Act, or is doing anything or about to do anything or permitting anything or about to permit anything to be done contrary to or in violation of law or any order, decision, rule, regulation, direction, or requirement of the Commission, issued or made under authority of this Act, the Commission shall file an action or proceeding in the circuit court in and for the county in which the case or some part thereof arose, or in which the person or corporation complained of, if any, has its principal place of business, or in which the person complained of, if any, resides, in the name of the People of the State of Illinois, for the purpose of having the violation or threatened violation stopped and prevented, either by mandamus or injunction.

The Commission may express its opinion in a resolution based upon whatever facts and evidence have come to its attention and may issue the resolution ex parte and without holding any administrative hearing before bringing suit. Except in cases involving an imminent threat to the public health or public safety, no such resolution shall be adopted until 48 hours after the public utility has been given notice of (i) the substance of the alleged violation, including a citation to the law or order, decision, rule, regulation, or direction of the Commission alleged to have been violated and (ii) the time and date of the meeting at which such resolution will first be before the Commission for consideration.

The Commission shall file the action or proceeding by complaint in the circuit court alleging the violation or threatened violation complained of and praying for appropriate relief by way of mandamus or injunction. It shall thereupon be the duty of the court to specify a time, not exceeding 20 days after the service of the copy of the complaint, within which the public utility complained of must answer the complaint, and in the meantime said public utility may be restrained. In case of default in answer, or after answer, the court shall immediately inquire into the facts and circumstances of the case. Such corporation or persons as the court may deem necessary or proper to be joined as parties, in order to make its judgment or order effective, may be joined as parties. The final judgment in any action or proceeding shall either dismiss the action or proceeding or grant relief by mandamus or injunction or be made permanent as prayed for in the complaint, or in such modified or other form as will afford appropriate relief. An appeal may be taken from such final judgment as in other civil cases.

(Source: P.A. 93-457, eff. 8-8-03.)

(220 ILCS 5/4-202.1)

Sec. 4-202.1. Enforcement of service area agreement between municipality and electric cooperative.

(a) The Commission shall approve, interpret, and enforce service area agreements between municipalities and electric cooperatives as provided in Section 11-117-1.1 of the Illinois Municipal Code.

(b) The provisions of this Section are severable under Section 1.31 of the Statute on Statutes.

(Source: P.A. 88-335.)

(220 ILCS 5/4-203) (from Ch. 111 2/3, par. 4-203)

Sec. 4-203. Action to recover penalties.

(a) All civil penalties established under this Act shall be assessed and collected by the Commission. Except for the penalties provided under Section 2-202, civil penalties may be assessed only after notice and opportunity to be heard. In determining the amount of the penalty, the Commission shall consider the appropriateness of the penalty to the size of the business of the public utility, corporation other than a public utility, or person acting as a public utility charged, the gravity of the violation, such other mitigating or aggravating factors as the Commission may find to exist, and the good faith of the public utility, corporation other than a public utility, or person acting as a public utility charged in attempting to achieve compliance after notification of a violation. Nothing in this Section, however, increases or decreases any minimum or maximum penalty prescribed elsewhere in this Act.

(b) If timely judicial review of a Commission order that imposes a civil penalty is taken by the public utility, corporation other than a public utility, or person acting as a public utility on which the civil penalty has been imposed, the reviewing court shall enter a judgment on all amounts upon affirmance of the Commission order. If timely judicial review is not taken and the civil penalty remains unpaid for 60 days after service of the order, the Commission in its discretion may either begin revocation proceedings or bring suit to recover the penalties. Unless stayed by a reviewing court, interest at the post-judgment rate set forth in Section 2-1303 of the Code of Civil Procedure shall accrue from 60 days after the date of service of the Commission order.

(c) Actions to recover delinquent civil penalties under this Act shall be brought in the name of the People of the State of Illinois in the circuit court in and for the county in which the cause, or some part thereof, arose, or in which the corporation complained of, if any, has its principal place of business, or in which the person, if any, complained of, resides. The action shall be commenced and prosecuted to final judgment by the Commission. In any such action, all interest incurred up to the time of final court judgment may be sued for and recovered in that action. In all such actions, the procedure and rules of evidence shall be the same as in ordinary civil actions, except as otherwise herein provided. All fines and penalties recovered by the State in any such action shall be paid into the State treasury to the credit of the General Revenue Fund. Any such action may be compromised or discontinued on application of the Commission upon such terms as the court shall approve and order.

(d) Civil penalties related to the late filing of reports, taxes, or other filings shall be paid into the State treasury to the credit of the Public Utility Fund. Except as otherwise provided in this Act, all other fines and civil penalties shall be paid into the State treasury to the credit of the General Revenue Fund.

(Source: P.A. 93-457, eff. 8-8-03.)

(220 ILCS 5/4-204) (from Ch. 111 2/3, par. 4-204)

Sec. 4-204. If the Secretary of State has dissolved or revoked the authority of any domestic or foreign company regulated under this Act to do business in Illinois because that company has not paid a franchise tax, license fee, filing fee, or penalty required under the Business Corporation Act of 1983 or under any other Illinois statute governing the formation or organization of domestic or foreign corporations, limited liability companies, partnerships, associations, or other organizations, then the franchise, license, permit, or right to engage in any business required under this Act shall be suspended by operation of law until such time within a one-year period after the date of suspension as the delinquent franchise tax, license fee, filing fee, or penalty is paid and revoked by operation of law for failure to pay the delinquent franchise tax, license fee, filing fee, or penalty within the one-year suspension period.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/4-205) (from Ch. 111 2/3, par. 4-205)

Sec. 4-205. This amendatory Act of 1985 shall not have the effect to release or waive any right of action by the State, the Commission, or by any body politic, municipal corporation, person or corporation for any right or penalty which may have arisen or accrued or may hereafter arise or accrue under this Act or any law of this State.

All penalties accruing under this Act shall be cumulative of each other, and suit for the recovery of one penalty shall not be a bar to or affect the recovery of any other penalty or be a bar to any criminal prosecution against any public utility, or any officer, director, agent or employee thereof, or any other corporation or person.

(Source: P.A. 84-617.)

(220 ILCS 5/4-301) (from Ch. 111 2/3, par. 4-301)

Sec. 4-301. The Commission may confer in person, or by correspondence, by attending conventions, or in any other way, with Commissions and any and all agencies dealing with public utilities of other states and of the United States on any matters relating to public utilities.

The Commission shall have full power and authority to make joint investigations, hold joint hearings within or without the State, and issue joint or concurrent orders in conjunction with any official, board, commission or agency of any state or of the United States. In the holding of such investigations or hearings, or in the making of such orders, the Commission shall function under agreements or compacts between states or under the concurrent power of states to regulate the interstate commerce, or as an agency of the United States, or otherwise.

The Commission shall make whenever requested by the Governor, the General Assembly, or either branch of the General Assembly a report within 90 days or any other time period specified within such request, which shall contain copies of all orders issued by the Commission which it deems of special importance or general significance, and any information in the possession of the Commission which it shall deem of value to the people of the State.

The Commission shall conduct a hearing and take testimony relative to any pending legislation with respect to any person, corporation or matter within its jurisdiction, if requested to do so by the Governor, the General Assembly, or either branch of the General Assembly, and shall report its conclusions to the Governor or the General Assembly, as the case may be. The Commission may also recommend the enactment of such legislation with respect to any matter within its jurisdiction as it deems wise or necessary in the public interest. The Commission shall, at such times as the Governor, the General Assembly, or either branch of the General Assembly shall direct, examine any particular subject connected with the condition and management of public utilities, and report to the Governor or the General Assembly, as the case may be, in writing its opinion thereon with its reasons therefor.

(Source: P.A. 98-15, eff. 5-22-13.)

(220 ILCS 5/4-302) (from Ch. 111 2/3, par. 4-302)

Sec. 4-302. The Commission shall cooperate with the Regional Transportation Authority created pursuant to the "Regional Transportation Authority Act", enacted by the 78th General Assembly, in the exercise of the powers of the Authority as provided in that Act.

Transportation Agencies which have any purchase of service agreement with a Service Board as provided in the "Regional Transportation Authority Act" shall not be subject to this Act as to any public transportation which is the subject of such agreement. Any service and business exempted from this Act pursuant to this Section shall not be considered "intrastate public utility business" as defined in Section 3-120 of this Act.

No contract between any Transportation Agency and the Authority or a Service Board or acquisition by the Authority or a Service Board of any property, including property of a Transportation Agency pursuant to and as defined in the Regional Transportation Authority Act, shall, except as provided in such Act, be subject to the supervision, regulation or approval of the Commission.

In the event a Service Board shall determine that any Public Transportation service provided by any Transportation Agency with which that Service Board has a Purchase of Service Agreement is not necessary for the public interest and shall for that reason decline to enter into any Purchase of Service Agreement for such particular service, all pursuant to and as defined in such Regional Transportation Authority Act, then the discontinuation of such service by such Transportation Agency shall not be subject to the supervision, regulation or approval of the Commission.

(Source: P.A. 84-617; 84-1025.)

(220 ILCS 5/4-303) (from Ch. 111 2/3, par. 4-303)

Sec. 4-303. Neither this Act nor any provision thereof shall apply or be construed to apply to commerce with foreign nations or commerce among the several states of this Union, except to the extent permitted under the provisions of the Constitution of the United States and Acts of Congress, and the applicable decisions of the courts of competent jurisdiction of this State or the United States.

(Source: P.A. 84-617; 84-1025.)

(220 ILCS 5/4-304) (from Ch. 111 2/3, par. 4-304)

Sec. 4-304. Beginning in 1986, the Commission shall prepare an annual report which shall be filed by January 31 of each year with the Joint Committee on Legislative Support Services of the General Assembly and the Governor and which shall be publicly available. Such report shall include:

(1) A general review of agency activities and changes, including:

(a) a review of significant decisions and other regulatory actions for the preceding year, and pending cases, and an analysis of the impact of such decisions and actions, and potential impact of any significant pending cases;

(b) for each significant decision, regulatory action and pending case, a description of the positions advocated by major parties, including Commission staff, and for each such decision rendered or action taken, the position adopted by the Commission and reason therefor;

(c) a description of the Commission's budget, caseload, and staff levels, including specifically:

(i) a breakdown by type of case of the cases resolved and filed during the year and of pending cases;

(ii) a description of the allocation of the Commission's budget, identifying amounts budgeted for each significant regulatory function or activity and for each department, bureau, section, division or office of the Commission and its employees;

(iii) a description of current employee levels, identifying any change occurring during the year in the number of employees, personnel policies and practices or compensation levels; and identifying the number and type of employees assigned to each Commission regulatory function and to each department, bureau, section, division or office of the Commission;

(d) a description of any significant changes in Commission policies, programs or practices with respect to agency organization and administration, hearings and procedures or substantive regulatory activity.

(2) A discussion and analysis of the state of each utility industry regulated by the Commission and significant changes, trends and developments therein, including the number and types of firms offering each utility service, existing, new and prospective technologies, variations in the quality, availability and price for utility services in different geographic areas of the State, and any other industry factors or circumstances which may affect the public interest or the regulation of such industries.

(3) A specific discussion of the energy planning responsibilities and activities of the Commission and energy utilities, including:

(a) the extent to which conservation, cogeneration, renewable energy technologies and improvements in energy efficiency are being utilized by energy consumers, the extent to which additional potential exists for the economical utilization of such supplies, and a description of existing and proposed programs and policies designed to promote and encourage such utilization;

(b) a description of each energy plan filed with the Commission pursuant to the provisions of this Act, and a copy, or detailed summary of the most recent energy plans adopted by the Commission;

(c) a discussion of the powers by which the Commission is implementing the planning responsibilities of Article VIII, including a description of the staff and budget assigned to such function, the procedures by which Commission staff reviews and analyzes energy plans submitted by the utilities, the Department of Natural Resources, and any other person or party; and

(d) a summary of the adoption of solar photovoltaic systems by residential and small business consumers in Illinois and a description of any and all barriers to residential and small business consumers' financing, installation, and valuation of energy produced by solar photovoltaic systems; electric utilities, alternative retail electric suppliers, and installers of distributed generation shall provide all information requested by the Commission or its staff necessary to complete the analysis required by this paragraph (d).

(4) A discussion of the extent to which utility services are available to all Illinois citizens including:

(a) the percentage and number of persons or households requiring each such service who are not receiving such service, and the reasons therefor, including specifically the number of such persons or households who are unable to afford such service;

(b) a critical analysis of existing programs designed to promote and preserve the availability and affordability of utility services; and

(c) an analysis of the financial impact on utilities and other ratepayers of the inability of some customers or potential customers to afford utility service, including the number of service disconnections and reconnections, and cost thereof and the dollar amount of uncollectible accounts recovered through rates.

(5) A detailed description of the means by which the Commission is implementing its new statutory responsibilities under this Act, and the status of such implementation, including specifically:

(a) Commission reorganization resulting from the addition of an Executive Director and administrative law judge qualifications and review;

(b) Commission responsibilities for construction and rate supervision, including construction cost audits, management audits, excess capacity adjustments, phase-ins of new plant and the means and capability for monitoring and reevaluating existing or future construction projects;

(c) promulgation and application of rules concerning ex parte communications, circulation of recommended orders and transcription of closed meetings.

(6) A description of all appeals taken from Commission orders, findings or decisions and the status and outcome of such appeals.

(7) A description of the status of all studies and investigations required by this Act, including those ordered pursuant to Sections 9-244 and 13-301 and all such subsequently ordered studies or investigations.

(8) A discussion of new or potential developments in federal legislation, and federal agency and judicial decisions relevant to State regulation of utility services.

(9) All recommendations for appropriate legislative action by the General Assembly.

The Commission may include such other information as it deems to be necessary or beneficial in describing or explaining its activities or regulatory responsibilities. The report required by this Section shall be adopted by a vote of the full Commission prior to filing.

(Source: P.A. 100-840, eff. 8-13-18; 101-81, eff. 7-12-19.)

(220 ILCS 5/4-305)

Sec. 4-305. (Repealed).

(Source: P.A. 88-226. Repealed by P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/4-401) (from Ch. 111 2/3, par. 4-401)

Sec. 4-401. If any Section, subdivision, sentence or clause of this Act is for any reason held invalid or to be unconstitutional, such decision shall not affect the validity of the remaining portions of this Act. A substantial compliance with the requirements of this Act shall be sufficient to give effect to all the Acts, orders, decisions, rules and regulations of the Commission and they shall not be declared inoperative, illegal or void for any omission of a technical nature in respect thereto.

(Source: P.A. 84-617.)

(220 ILCS 5/4-402) (from Ch. 111 2/3, par. 4-402)

Sec. 4-402. This amendatory Act of 1985 shall not affect pending actions or proceedings, civil or criminal, in any court or other tribunal brought by or against the People of the State of Illinois or the Illinois Commerce Commission or by any other person, firm or corporation under the provisions of this Act or any other Act establishing or conferring power on the Commission, nor abate any causes of action arising thereunder, but the same may be instituted, prosecuted and defended with the same effect as though this amendatory Act had not been passed. Any investigation, hearing or proceeding, instituted or conducted by the Commission prior to the taking effect of this amendatory Act shall be conducted and continued to a final determination by the Commission with the same effect as if this amendatory Act had not been passed.

All findings, orders, decisions, rules and regulations issued or promulgated by the Commission under this Act or any other Act establishing or conferring power on the Commission, shall continue in force; and the Commission hereby created shall have all powers with respect to said findings, orders, decisions, rules and regulations as though said findings, orders, decisions, rules and regulations had been made, issued or promulgated by the Commission under this amendatory Act. Notwithstanding the provisions of this Section, where applicable, the Commission shall amend its findings, orders, decisions, rules and regulations to conform to the provisions of this Act as soon as practicable after the effective date.

(Source: P.A. 84-617.)

(220 ILCS 5/4-404)

Sec. 4-404. Protection of confidential and proprietary information. The Commission shall provide adequate protection for confidential and proprietary information furnished, delivered or filed by any person, corporation or other entity, including proprietary information provided to the Commission by the Illinois Power Agency.

(Source: P.A. 95-481, eff. 8-28-07.)

(220 ILCS 5/4-501)

Sec. 4-501. Small public utilities and telecommunications carriers; circuit court appointment of receiver; bond.

(a) If a public utility or telecommunications carrier that has fewer than 7,500 customers:

(1) is unable or unwilling to provide safe, adequate, or reliable service;

(2) no longer possesses sufficient technical, financial, or managerial resources and abilities to provide safe, adequate, or reliable service;

(3) has been actually or effectively abandoned by its owners or operators;

(4) has defaulted on a bond, note, or loan issued or guaranteed by a department, office, commission, board, authority, or other unit of State government;

(5) has failed to comply, within a reasonable period of time, with an order of the Commission concerning the safety, adequacy, efficiency, or reasonableness of service; or

(6) has allowed property owned or controlled by it to be used in violation of a final order of the Commission;

the Commission may file a petition for receivership and a verifying affidavit executed by the executive director of the Commission or a person designated by the executive director asking the circuit court for an order attaching the assets of the public utility or telecommunications carrier and placing the public utility or telecommunications carrier under the control and responsibility of a receiver.

(b) The court shall hold a hearing within 5 days of the filing of the petition. The petition and notice of the hearing shall be served upon the owner or designated agent of the public utility or telecommunications carrier as provided under the Civil Practice Law, or the petition and notice of hearing shall be posted in a conspicuous area at a location where the public utility or telecommunications carrier normally conducts its business affairs, not later than 3 days before the time specified for the hearing unless a different period is fixed by order of court.

If a petition for receivership and verifying affidavit executed by the executive director of the Commission or the person designated by the executive director allege an immediate and serious danger to residents constituting an emergency, the court shall set the matter for hearing within 3 days and may appoint a temporary receiver ex parte upon the strength of the petition and affidavit pending a full evidentiary hearing. The court shall hold a full evidentiary hearing on the petition within 5 days of the appointment of the temporary receiver. The public utility or telecommunications carrier shall be served with the petition, affidavit, and notice of hearing in the manner provided in this subsection not later than 3 days before the time specified for the full evidentiary hearing, unless a different period is fixed by order of court.

(c) After a hearing, the court shall determine whether to grant the petition. A receiver appointed under this Section shall be a responsible person, partnership, or corporation knowledgeable in the operation of the type of public utility or telecommunications carrier that is the subject of the petition for receivership.

(d) A receiver appointed by the court shall file a bond. The receiver shall operate the public utility or telecommunications carrier to preserve its assets and to serve the best interests of its customers. The receiver appointed shall directly or by its agents and attorneys enter upon and take possession of the public utility's or telecommunications carrier's facilities and operations and may exclude from the public utility's or telecommunications carrier's facilities any or all of the public utility's or telecommunications carrier's officers, agents, or employees and all persons claiming under them. The receiver shall have possession and control the facilities and shall exercise all rights and powers with respect to the facilities that could be exercised by the public utility or telecommunications carrier. The receiver shall maintain, restore, insure, and make all proper repairs to the public utility or telecommunications facilities. The receiver shall have the powers and duties necessary for the continued operation of the public utility or telecommunications carrier and the provision of continuous and adequate services to customers.

(e) The receiver shall, in the performance of the powers conferred, act under the supervision of the court making the appointment. The receiver is at all times subject to the orders of the court and may be removed by the court. The court may enter other orders that it considers appropriate for the exercise by the receiver of functions specifically set forth in this Section. The receiver shall be compensated from the assets of the public utility or telecommunications carrier in an amount to be determined by the court. In addition, in a suit, action, or proceeding by or against the receiver of a public utility or telecommunications carrier, the fees, counsel fees, and expenses of the receiver, if any, that are incurred to prosecute or defend the suit, action, or proceeding shall be paid out of the assets of the public utility or telecommunications carrier.

(f) If the receiver determines that the public utility's or telecommunications carrier's actions that caused it to be placed under the control and responsibility of the receiver were due to misappropriation or wrongful diversion of the assets or income of the company or to other misconduct by a director, officer, or manager of the company, the receiver shall file a petition with the circuit court that issued the order of receivership for an order that the director, officer, or manager be ordered to pay compensatory damages to the company because of the misappropriation, diversion, or misconduct.

(g) Control of and responsibility for the public utility or telecommunications carrier shall remain in the receiver until, upon a showing of good cause by the public utility or telecommunications carrier, the court determines that it is in the best interests of its customers that the public utility or telecommunications carrier be returned to the owners or the court determines that the receiver is no longer required. The court may also direct the receiver to liquidate the assets of the public utility or telecommunications carrier in the manner provided by law.

(h) The appointment of a receiver shall be in addition to any other remedies provided by law.

(Source: P.A. 91-357, eff. 7-29-99.)

(220 ILCS 5/4-502)

Sec. 4-502. Small public utility or telecommunications carrier; acquisition by capable utility; Commission determination; procedure.

(a) The Commission may provide for the acquisition of a small public utility or telecommunications carrier by a capable public utility or telecommunications carrier, if the Commission, after notice and an opportunity to be heard, determines one or more of the following:

(1) the small public utility or telecommunications carrier is failing to provide safe, adequate, or reliable service;

(2) the small public utility or telecommunications carrier no longer possesses sufficient technical, financial, or managerial resources and abilities to provide the service or services for which its certificate was originally granted;

(3) the small public utility or telecommunications carrier has been actually or effectively abandoned by its owners or operators;

(4) the small public utility or telecommunications carrier has defaulted on a bond, note, or loan issued or guaranteed by a department, office, commission, board, authority, or other unit of State government;

(5) the small public utility or telecommunications carrier has wilfully failed to comply with any provision of this Act, any other provision of State or federal law, or any rule, regulation, order, or decision of the Commission; or

(6) the small public utility or telecommunications carrier has wilfully allowed property owned or controlled by it to be used in violation of this Act, any other provision of State or federal law, or any rule, regulation, order, or decision of the Commission.

(b) As used in this Section, "small public utility or telecommunications carrier" means a public utility or telecommunications carrier that regularly provides service to fewer than 7,500 customers.

(c) In making a determination under subsection (a), the Commission shall consider all of the following:

(1) The financial, managerial, and technical ability of the small public utility or telecommunications carrier.

(2) The financial, managerial, and technical ability of all proximate public utilities or telecommunications carriers providing the same type of service.

(3) The expenditures that may be necessary to make improvements to the small public utility or telecommunications carrier to assure compliance with applicable statutory and regulatory standards concerning the adequacy, efficiency, safety, or reasonableness of utility service.

(4) The expansion of the service territory of the acquiring capable public utility or telecommunications carrier to include the service area of the small public utility or telecommunications carrier to be acquired.

(5) Whether the rates charged by the acquiring capable public utility or telecommunications carrier to its acquisition customers will increase unreasonably because of the acquisition.

(6) Any other matter that may be relevant.

(d) For the purposes of this Section, a "capable public utility or telecommunications carrier" means a public utility, as defined under Section 3-105 of this Act, including those entities listed in items (1) through (5) of subsection (b) of Section 3-105, or a telecommunications carrier, as defined under Section 13-202 of this Act, including those entities listed in subsections (a) and (b) of Section 13-202, that:

(1) regularly provides the same type of service as the small public utility or telecommunications carrier, to 7,500 or more customers, and provides safe, adequate, and reliable service to those customers; however, public utility or telecommunications carrier that would otherwise be a capable public utility except for the fact that it has fewer than 7,500 customers may elect to be a capable public utility or telecommunications carrier for the purposes of this Section regardless of the number of its customers and regardless of whether or not it is proximate to the small public utility or telecommunications carrier to be acquired;

(2) is not an affiliated interest of the small public utility or telecommunications carrier;

(3) agrees to acquire the small public utility or telecommunications carrier that is the subject of the proceeding, under the terms and conditions contained in the Commission order approving the acquisition; and

(4) is financially, managerially, and technically capable of acquiring and operating the small public utility or telecommunications carrier in compliance with applicable statutory and regulatory standards.

(e) The Commission may, on its own motion or upon petition, initiate a proceeding in order to determine whether an order of acquisition should be entered. Upon the establishment of a prima facie case that the acquisition of the small public utility or telecommunications carrier would be in the public interest and in compliance with the provisions of this Section all of the following apply:

(1) The small public utility or telecommunications carrier that is the subject of the acquisition proceedings has the burden of proving its ability to render safe, adequate, and reliable service at just and reasonable rates.

(2) The small public utility or telecommunications carrier that is the subject of the acquisition proceedings may present evidence to demonstrate the practicality and feasibility of the following alternatives to acquisition:

(A) the reorganization of the small public utility or telecommunications carrier under new management;

(B) the entering of a contract with another public utility, telecommunications carrier, or a management or service company to operate the small public utility or telecommunications carrier;

(C) the appointment of a receiver to operate the small public utility or telecommunications carrier, in accordance with the provisions of Section 4-501 of this Act; or

(D) the merger of the small public utility or telecommunications carrier with one or more other public utilities or telecommunications carriers.

(3) A public utility or telecommunications carrier that desires to acquire the small public utility or telecommunications carrier has the burden of proving that it is a capable public utility or telecommunications carrier.

(f) Subject to the determinations and considerations required by subsections (a), (b), (c), (d) and (e) of this Section, the Commission shall issue an order concerning the acquisition of the small public utility or telecommunications carrier by a capable public utility or telecommunications carrier. If the Commission finds that the small public utility or telecommunications carrier should be acquired by the capable public utility or telecommunications carrier, the order shall also provide for the extension of the service area of the acquiring capable public utility or telecommunications carrier.

(g) The price for the acquisition of the small public utility or telecommunications carrier shall be determined by agreement between the small public utility or telecommunications carrier and the acquiring capable public utility or telecommunications carrier subject to a determination by the Commission that the price is reasonable. If the small public utility or telecommunications carrier and the acquiring capable public utility or telecommunications carrier are unable to agree on the acquisition price or the Commission disapproves the acquisition price upon which they have agreed, the Commission shall issue an order directing the acquiring capable public utility or telecommunications carrier to acquire the small public utility or telecommunications carrier by following the procedure prescribed for the exercise of the powers of eminent domain under Section 8-509 of this Act.

(h) The Commission may, in its discretion and for a reasonable period of time after the date of acquisition, allow the acquiring capable public utility or telecommunications carrier to charge and collect rates from the customers of the acquired small public utility or telecommunications carrier under a separate tariff.

(i) A capable public utility or telecommunications carrier ordered by the Commission to acquire a small public utility or telecommunications carrier shall submit to the Commission for approval before the acquisition a plan, including a timetable, for bringing the small public utility or telecommunications carrier into compliance with applicable statutory and regulatory standards.

(Source: P.A. 95-481, eff. 8-28-07.)

(220 ILCS 5/4-601)

Sec. 4-601. Consumer protection laws.

(a) The General Assembly finds that consumer protection is vital to the health, safety, and welfare of Illinois consumers.

(b) Notwithstanding any other provision of law, the Commission and its staff shall:

(1) work cooperatively with law enforcement authorities, including the Attorney General and State's Attorneys, in their enforcement of consumer protection laws, including the Consumer Fraud and Deceptive Business Practices Act;

(2) provide any materials or documents already in the Commission's possession requested by the Attorney General or a State's Attorney pertaining to the enforcement of consumer protection laws; any materials or documents that are proprietary shall not be made public unless the designation as proprietary has been removed by a court or legal body of competent jurisdiction, or the agreement of the parties; and

(3) upon written request, forward any complaints regarding alleged violations of any consumer protection law to the Attorney General and the State's Attorney of the appropriate county or counties.

(c) Subject to subdivision (1) of Section 10b of the Consumer Fraud and Deceptive Business Practices Act, the Attorney General and the State's Attorney of any county shall have available all remedies and authority granted to them by the Consumer Fraud and Deceptive Business Practices Act. The remedies for violations of this Act and its rules are not intended to replace other remedies that may be imposed for violations of the Consumer Fraud and Deceptive Business Practices Act and are in addition to, and not in substitution for, such other remedies, nor is this Act intended to remove any statutorily defined defenses.

(Source: P.A. 93-881, eff. 1-1-05.)

(220 ILCS 5/4-602)

Sec. 4-602. Electric utility workforce study.

(a) The Commission shall conduct a comprehensive workforce analysis study of each electric utility to determine the adequacy of the total in-house staffing in each job classification or job title critical to maintaining quality reliability and restoring service in each electric utility's service territory. Each report shall contain a yearly detailed comparison beginning with 1995 and ending in 2006 of each electric utility's ratio of:

(1) in-house workers, commonly referred to as "linemen", to customers;

(2) customer service call-center employees to customers; and

(3) meter service or repair employees to customers.

The ratios shall be reported from each utility's named service area, district, division, outlying area, village, municipality, reporting point, or region. The analysis shall determine the total number of contractor employees for the same time frame and shall be conducted in the same manner as the in-house analysis.

(b) The Commission may hold public hearings while conducting the analysis to assist in the adequacy of the study. The Commission must hold public hearings on the study and present the results to the General Assembly no later than January 1, 2009.

(c) An electric utility shall bear the costs of issuing any reports required by this Section and it shall not be entitled to recovery of any costs incurred in complying with this Section.

(Source: P.A. 95-81, eff. 8-13-07.)

(220 ILCS 5/4-603)

Sec. 4-603. Adequate employment for in-house utility employees. The staff of the Commission shall develop benchmarks for employee staffing levels for each classification and employee training for each classification, subject to the requirements of Section 4-602 of this Act, within one year after the effective date of this amendatory Act of the 96th General Assembly.

(Source: P.A. 95-81, eff. 8-13-07; 96-582, eff. 8-18-09.)

(220 ILCS 5/4-604)

Sec. 4-604. Electric and gas public utilities ethical conduct and transparency.

(a) It is the policy of this State that, as regulated, monopoly entities providing essential services, public utilities must adhere to the highest standards of ethical conduct. It is in the public interest to ensure ethical public utility conduct of the highest standards. It is therefore necessary for the public interest, safety, and welfare of the State and of public utility customers to develop rigorous ethical standards and scrutinize and limit public utility actions, expenditures, and contracting. It is also necessary to provide increased transparency to ensure ethical public utility conduct.

(b) The standards set forth in this Section and the Illinois Administrative Code rules implementing this Section shall apply, to the extent practicable, to electric and gas public utilities and their energy-related affiliates.

(c) Public Utility Ethics and Compliance Monitor. To ensure that public utilities meet the highest level of ethical standards, including, but not limited to, those standards established in this Section, the Commission shall, within 60 days after the effective date of this amendatory Act of the 102nd General Assembly, establish an Ethics and Accountability Division at the Commission and shall create a new position of Public Utility Ethics and Compliance Monitor who reports to the Executive Director of the Commission. The role of the Public Utility Ethics and Compliance Monitor shall be to oversee electric and gas public utilities' compliance with the standards established in this Section, the Illinois Administrative Code, and any other regulatory or statutory obligation regarding standards of ethical conduct. The responsibilities of the Public Utility Ethics and Compliance Monitor shall include:

(1) Hiring additional staff for the Ethics and Accountability Division, as deemed necessary to fulfill the duties imposed under this Section.

(2) Overseeing each public utility's Chief Compliance and Ethics Officer's monitoring, auditing, investigation, enforcement, reporting, disciplinary activities, and any other actions required of the Chief Compliance and Ethics Officer pursuant to subsection (d) of this Section. If the Public Utility Ethics and Compliance Monitor finds a public utility has not complied with the standards set forth in this Section, or with administrative rules implementing this Section, the Public Utility Ethics and Compliance Monitor shall detail such deficiencies in a report to the Commission and shall include a recommendation for Commission action.

(3) Documenting violations of the standards in this Section or in related Sections of the Illinois Administrative Code and, in coordination with the utility's Chief Compliance and Ethics Officer, ensuring each public utility administers appropriate internal disciplinary actions and provides transparent reporting to the Commission. If there are violations of the standards in this Section or in related Sections of the Illinois Administrative Code where the public utility does not take disciplinary action or where that action is not aligned with the recommendation of the Public Utility Ethics and Compliance Monitor, the Public Utility Ethics and Compliance Monitor shall, within 30 days, report the violation, the recommended disciplinary action, and the public utility's actual disciplinary action, to the Executive Director of the Commission. Such reports shall be included in the annual ethics report required by paragraph (5) of this subsection (c) and must describe the violation and related recommendations.

(4) Reviewing and keeping informed regarding internal controls, code of ethical conduct, practices, procedures, and conduct of each public utility. The Public Utilities Ethics and Compliance Monitor may recommend any new internal controls, policies, practices or procedures the public utility should undertake in order to ensure compliance with this Section and with relevant Sections of the Illinois Administrative Code.

(5) Publishing an annual ethics audit for each electric and gas public utility describing the public utility's internal controls, policies, practices, and procedures to comply with statutes, rules, court orders, or other applicable authority. The report shall include a record of any disciplinary actions taken related to unethical conduct as well as any recommendations made by the Public Utility Ethics and Compliance Monitor and the public utility's response to each recommendation. This report must be made public and the Commission may make necessary redactions.

(6) Monitoring, auditing, and subpoenaing all records necessary for the Public Utility Ethics and Compliance Monitor to meet the responsibilities imposed under this Section and related rules, including, but not limited to, contracts with third party entities, accounting records, communication with public officials or their staff, lobbying activities, expenses on lobbyists and consultants, legal expenses, and internal compliance policies.

(d)(1) No later than 60 days after the effective date of this amendatory Act of the 102nd General Assembly, each public utility shall establish a position of Chief Ethics and Compliance Officer if such position does not already exist within the utility or at an affiliated company, provided that if the position exists at an affiliated company such individual may be designated to serve in this role for the utility. The Chief Ethics and Compliance Officer shall be responsible for ensuring that the public utility complies with the highest standards of ethical conduct, including, but not limited to, complying with the standards imposed under this Section, those adopted pursuant to a rulemaking authorized by this Section, and other applicable requirements of Illinois law and rules.

(2) Each public utility's Chief Ethics and Compliance Officer shall:

(A) oversee creation and implementation of a code of ethical conduct for the public utility, applicable to all directors, officers, employees, and lobbyists of the public utility, as well as to all contractors, consultants, agents, vendors, and business partners of the public utility in connection with their activities with or on behalf of the public utility;

(B) oversee training for public utility directors, officers, and employees, as well as contractors, consultants, lobbyists and political consultants, on the public utility's code of ethical conduct, practices, and procedures to advise agents, vendors, and business partners of the public utility of the applicability of the code of ethical conduct to their activities with or on behalf of the public utility;

(C) oversee the ongoing monitoring of all contractors, consultants, and vendors who are contracted for the purpose of carrying out lobbying activities to ensure their continued compliance with applicable ethical standards;

(D) at least annually, oversee a review of the public utility's internal controls, code of ethical conduct, practices, and procedures to assess their continued effectiveness to ensure the highest standards of ethical conduct among the public utility's directors, officers, employees, contractors, consultants, lobbyists, vendors, agents and business partners; and

(E) maintain records of all conduct determined to be in violation of Illinois law, rules, and regulations, and the utility's response to that conduct, and make such records available for inspection by the Public Utility Ethics and Compliance Monitor.

(e) In addition to those standards established under this Section, those adopted pursuant to a rulemaking authorized by this Section, and other applicable requirements of Illinois law and rules, each public utility Chief Ethics and Compliance Officer shall oversee and ensure the development and implementation of internal controls, policies, and procedures to achieve the objectives set forth in paragraphs (1) through (3) of this subsection. Such implementation shall begin no later than 90 days after the effective date of this amendatory Act of the 102nd General Assembly.

(1) The hiring of contractors, consultants and vendors for the purpose of carrying out lobbying pursuant to the Lobbyist Registration Act shall be reviewed and approved by the Chief Ethics and Compliance Officer.

(2) No agreement between a public utility and a contractor, consultant, or vendor engaged for the purpose of carrying out lobbying pursuant to the Lobbyist Registration Act shall permit that contractor, consultant, or vendor to subcontract any portion of that work.

(3) Public utilities shall require contractors, consultants, and vendors who are contracted for the purpose of carrying out lobbying pursuant to the Lobbyist Registration Act to provide detailed invoices and reports describing activities taken and amounts billed for such activities, including all persons involved and anything of value requested or solicited or provided to public officials or their staff, including hiring requests. No such contractor, consultant, or vendor shall be paid without having first submitted a detailed invoice or report.

For purposes of this Section, "anything of value" includes, but is not limited to, money, gifts, entertainment, hiring referrals and recommendations to the public utility, campaign contributions, vendor referrals, and contributions to charitable organizations solicited by or on behalf of the public official.

(f) Each public utility shall be required to submit an annual ethics and compliance report to the Commission no later than May 1 of each year, beginning May 1, 2022. The utility's Chief Ethics and Compliance Officer shall oversee the preparation and submission of the report and shall certify it. Each report shall describe in detail the public utility's internal controls, codes of ethical conduct, practices, and procedures. The reporting implemented during the reporting period to comply with the standards set forth in this Section, rules adopted by the Commission, and other applicable requirements of Illinois law and rules. Each report shall also identify any material changes implemented to such internal controls, code of ethical conduct, practices, and procedures during the reporting period, as well as any material changes implemented, or anticipated to be implemented, in the calendar year in which the report is filed. Each report shall, for the applicable reporting period include at least the following information:

(1) a summary and description of the public utility's system of financial and accounting procedures, internal controls, and practices, including an explanation of how this system is reasonably designed to ensure the maintenance of fair and accurate books, records, and accounts and to provide reasonable assurances that transactions are recorded as necessary to permit preparation of financial statements in conformity with generally accepted accounting principles and Commission requirements and to maintain accountability for assets;

(2) a summary and description of the public utility's process for conducting an assessment of ethics and compliance risks and a representation that an assessment was conducted in accordance with those risks and shared with the public utility's senior management and board of directors;

(3) a summary of the public utility's implementation of mechanisms, including, but not limited to, training programs designed to ensure that its internal controls, code of ethical conduct, practices, and procedures are effectively communicated to all directors, officers, employees, contractors, consultants, lobbyists, vendors, agents, and business partners;

(4) a summary of the public utility's efforts to ensure that its directors and senior management provide strong, explicit, and visible support and commitment to its corporate policy against violations of federal and State law;

(5) a summary of the public utility's implementation of mechanisms designed to effectively enforce its internal controls, code of ethical conduct, practices, and procedures, including appropriately providing incentives for compliance, disciplining violators, and applying such code, controls, policies, practices, and procedures consistently and fairly regardless of the position held by, or the importance of, the director, officer, or employee; and

(6) a summary of the public utility's implementation of procedures to ensure that, where misconduct is discovered, reasonable steps are taken to remedy the harm resulting from such misconduct, including disciplinary action, logging the conduct and the utility's response as required by item (E) of paragraph (2) of subsection (d) of this Section and assessing and modifying as appropriate the internal controls, code, policies, practices and procedures necessary to ensure that the compliance program is effective.

For purposes of this Section, "reporting period" means the most recent 12-month calendar year period preceding the applicable May 1 annual report filing date.

(g) Notwithstanding the provisions of this Section, the Commission shall initiate a management audit pursuant to Section 8-102 of this Act by the later of 18 months after the effective date of this amendatory Act of the 102nd General Assembly or 18 months after a conviction or a plea or agreement of each public utility that, on or after January 1, 2020, has been found guilty or entered a guilty plea regarding any felony offense or has entered into a Deferred Prosecution Agreement for a felony offense. Such audit shall address, at a minimum, the topics identified in paragraphs (1) through (6) of subsection (f).

(h) Each public utility that files a report pursuant to subsection (f) must submit the specified filing fee at the time the Chief Clerk of the Commission accepts the filing. The filing fees applicable to each annual report are as follows: $15,000 for public utilities that serve fewer than 100,000 customers in the State; $75,000 for public utilities that serve at least 100,000 customers but not more than 500,000 customers in the State; $200,000 for public utilities that serve at least 500,000 customers in the State but not more than 3,000,000; and $500,000 for public utilities that serve at least 3,000,000 customers in the State.

(i) In the event the Public Utility Ethics and Compliance Monitor finds a public utility does not comply with any portion of this Section, or with the rules adopted under this Section, the Public Utility Ethics and Compliance Monitor shall issue a Report to the Commission detailing the public utility's deficiencies. The Commission shall have authority to open an investigation and shall order remediation and penalties, including fines, as appropriate.

(j) Each year, each public utility in the State shall remit amounts necessary for the Commission to pay the wages, overhead, travel expenses, and other costs of the Public Utility Ethics and Compliance Monitor. The public utility shall remit payment to the Commission in an amount determined by the Commission based on that public utility's proportional share, by number of customers.

(k) The costs of a public utility that arise from a criminal investigation or result from an investigation initiated by the Commission as the result of an ethics violation are not costs of service and shall not be recoverable in rates.

(l) The Commission shall have the authority to adopt rules and emergency rules where applicable to implement this Section.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/4-604.5)

Sec. 4-604.5. Restitution for misconduct.

(a) It is the policy of this State that public utility ethical and criminal misconduct shall not be tolerated. The General Assembly finds it necessary to collect restitution, to be distributed as described in subsection (e), from a public utility that has been found guilty of violations of criminal law or that has entered into a Deferred Prosecution Agreement that details violations of criminal law that result in harm to ratepayers.

(b) In light of such violations, the Illinois Commerce Commission shall, within 150 days after the effective date of this amendatory Act of the 102nd General Assembly, initiate an investigation as to whether Commonwealth Edison collected, spent, allocated, transferred, remitted, or caused in any other way to be expended ratepayer funds in connection with the conduct detailed in the Deferred Prosecution Agreement of July 16, 2020 between the United States Attorney for the Northern District of Illinois and Commonwealth Edison. The investigation shall also determine whether any ratepayer funds were used to pay the criminal penalty agreed to in the Deferred Prosecution Agreement. The investigation shall determine whether the public utility collected, spent, allocated, transferred, remitted, or caused in any other way to be expended ratepayer funds that were not lawfully recoverable through rates, and which should accordingly be refunded to ratepayers and calculate such benefits to initiate a refund to ratepayers as a result of such conduct. The investigation shall conclude no later than 330 days following initiation and shall be conducted as a contested case, as defined in Section 1-30 of the Illinois Administrative Procedure Act.

(c) If regulated entities are found guilty of criminal conduct, the Commission may initiate an investigation, impose penalties, order restitution and such other remedies it deems necessary, and initiate refunds to ratepayers as described in subsection (b). Such investigation and proceeding may commence within 150 days of a finding of guilt. Any funds collected pursuant to this subsection shall be distributed as described in subsection (e). The Commission may order any other remedies it deems necessary.

(d) Pursuant to subsection (e), the investigation shall calculate a schedule for remittance to State funds and to ratepayers, over a period of no more than 4 years, to be paid by the public utility from profits, returns, or shareholder dollars. No costs related to the investigation or contested proceeding authorized by this Section, restitution, or refunds may be recoverable through rates.

(e) Funds collected pursuant to this Section, for the purposes of restitution, shall be repaid by the public utility as a per therm or per-kilowatt-hour credit to the public utility's ratepayers as a separate line item on the utility bill.

(f) No public utility may use ratepayer funds to pay a criminal penalty imposed by any local, State, or federal law enforcement entity or court.

(g) Any penalties, restitution, refunds, or remedies provided for in this Section are in addition to and not a substitution for other remedies that may be provided for by law.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/4-605)

Sec. 4-605. Reliability mitigation plan findings. The General Assembly finds that reducing carbon dioxide and copollutant emissions in a manner that does not threaten electric reliability and resource adequacy is essential to the health and safety of all Illinois citizens. Therefore, the Commission shall review reliability mitigation plans filed pursuant to Section 9.15 of the Environmental Protection Act to ensure adequate, reliable, affordable, efficient, and environmentally sustainable electric service is available to ratepayers by approving reliability mitigation plans that permit the Illinois Pollution Control Board to enforce emission reductions in a manner that preserves reliability and resource adequacy in wholesale and retail electricity markets.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/4-610)

Sec. 4-610. Thermal energy networks.

(a) The General Assembly finds that:

(1) the State has an interest in decarbonizing buildings in a manner that is affordable and accessible, preserves and creates living-wage jobs, and retains the knowledge and experience of the existing utility workforce;

(2) thermal energy networks have the potential to affordably decarbonize buildings at the community-scale and utility-scale and help achieve the goals of the Climate and Equitable Jobs Act (Public Act 102-662);

(3) the construction industry is highly skilled and labor intensive, and the installation of modern thermal energy networks involves particularly complex work, therefore effective qualification standards for craft labor personnel employed on these projects are critically needed to promote successful project delivery; and

(4) it is the intent of the General Assembly to establish a stakeholder workshop within the Commission to promote the successful planning and delivery of thermal energy networks in an equitable manner that reduces emissions, offers affordable building decarbonization, and provides opportunities for employment with fair labor standards and preapprenticeship and apprenticeship programs.

(b) As used in this Section:

"Thermal energy" means piped noncombustible fluids used for transferring heat into and out of buildings for the purpose of reducing any resultant onsite greenhouse gas emissions of all types of heating and cooling processes, including, but not limited to, comfort heating and cooling, domestic hot water, and refrigeration.

"Thermal energy network" means all real estate, fixtures, and personal property operated, owned, used, or to be used for, in connection with, or to facilitate a utility-scale distribution infrastructure project that supplies thermal energy.

(c) The Commission, in order to develop a regulatory structure for utility thermal energy networks that scale with affordable and accessible building electrification, protect utility customers, and promote the successful planning and delivery of thermal energy networks, shall convene a workshop process for the purpose of establishing an open, inclusive, and cooperative forum regarding such thermal energy networks. The workshops may be facilitated by an independent, third-party facilitator selected by the Commission. The series of workshops shall include no fewer than 3 workshops. After the conclusion of the workshops, the Commission shall open a comment period that allows interested and diverse stakeholders to submit comments and recommendations regarding the thermal energy networks. Based on the workshop process and stakeholder comments and recommendations offered verbally or in writing during the workshops and in writing during the comment period following the workshops, the Commission or, if applicable, the independent third-party facilitator, shall prepare a report, to be submitted to the Governor and the General Assembly no later than March 1, 2024, describing the stakeholders, discussions, proposals, and areas of consensus and disagreement from the workshop process, and making recommendations regarding thermal energy networks.

(d) The workshop shall be designed to achieve the following objectives:

(1) determine appropriate ownership, market, and rate structures for thermal energy networks and whether the provision of thermal energy services by thermal network energy providers is in the public interest;

(2) consider project designs that could maximize the value of existing State energy efficiency and weatherization programs and maximize federal funding opportunities to the extent practicable;

(3) determine whether thermal energy network projects further climate justice and emissions reductions and benefits to utility customers and society at large, including but not limited to public health benefits in areas with disproportionate environmental burdens, job retention and creation, reliability, and increased affordability of renewable thermal energy options;

(4) consider approaches to thermal energy network projects that advance financial and technical approaches to equitable and affordable building electrification, including access to thermal energy network benefits by low and moderate income households; and

(5) consider approaches to promote the training and transition of utility workers to work on thermal energy networks.

(Source: P.A. 103-580, eff. 12-8-23.)

(220 ILCS 5/4-615)

Sec. 4-615. Training for carbon dioxide emergencies.

(a) Prior to any pipeline for the transportation of carbon dioxide becoming operational, the Illinois Fire Service Institute, in coordination with the Office of the State Fire Marshal, an EMS System, the Department of Public Health, and the Illinois Emergency Management Agency and Office of Homeland Security, shall develop and offer at least one course for first responders who respond when carbon dioxide is released from a pipeline or a sequestration facility. At a minimum, the course shall cover:

(1) how to identify a carbon dioxide release;

(2) communications procedures to quickly share information about a carbon dioxide release, including alarms, sirens, text message alerts, and other means of alerting the public;

(3) procedures for locating residents and others in the affected area and, when necessary, transporting residents and others in the affected area out of the area to health care facilities; and

(4) signs and symptoms of exposure to a carbon dioxide release.

(b) Each year thereafter, the Illinois Fire Service Institute, in coordination with the Office of the State Fire Marshal, an EMS System and the Department of Public Health, shall offer a training session at the Illinois Fire Service Institute's Regions for Training Delivery on emergency response procedures during carbon dioxide releases. These trainings shall be available to first responders in the State with priority participation given to counties in which carbon dioxide is proposed to be or is transported or sequestered.

(c) Prior to a carbon dioxide pipeline becoming operational, the owner or operator of the pipeline shall develop, in coordination with the Illinois Emergency Management Agency and Office of Homeland Security and Department of Public Health, emergency preparedness materials for residents and local businesses in the counties within 2 miles of where the owner or operator is transporting or sequestering carbon dioxide. At a minimum, these materials shall include:

(1) what to do in the event of a carbon dioxide release;

(2) symptoms of exposure to a carbon dioxide release; and

(3) recommendations for items residents and local businesses may want to acquire, including, but not limited to, carbon dioxide monitors and air supply respirators.

The Illinois Emergency Management Agency and Office of Homeland Security and the Department of Public Health shall publish this information on their websites and provide these materials to local emergency management agencies and local public health departments in relevant counties.

(d) For each carbon dioxide pipeline, the owner or operator of the pipeline shall use modeling that can handle non-flat terrain; obstacles, such as vegetation and buildings; time or spatial variations in wind, including direction and speed; ambient weather conditions, such as temperature and humidity; variations to the direction of release of CO2; and concentrations and durations of CO2, in addition to the specifics related to the pipeline design, including, but not limited to, diameter, thickness, and shutoff valves, to develop a risk-based assessment and a chemical safety contingency plan. The Illinois Emergency Management Agency and Office of Homeland Security shall publish this information on its website and provide these materials to local emergency management agencies in relevant counties.

(e) Each year, the owner or operator of a pipeline, in coordination with Department of Public Health and local emergency response personnel, shall offer at least 2 public training sessions for residents and local businesses in every county in which carbon dioxide is transported or sequestered. These trainings shall be offered in person and virtually. Each training shall be recorded and provided to Illinois Emergency Management Agency and Office of Homeland Security and the Department of Public Health to maintain a copy on their websites, as appropriate, with the emergency preparedness materials identified in subsection (c).

(f) Each year, the owner or operator of the pipeline shall develop, in coordination with the Department of Public Health, and offer a training session for medical personnel in each county along the pipeline route, including staff in hospitals and emergency rooms, health clinics, and other health care facilities. These trainings shall be offered in person and virtually and be approved by the Department of Public Health. Each training shall be recorded and provided to the Department of Public Health to maintain a copy on its website, as appropriate, and distribute to staff in hospitals and emergency rooms, health clinics, and other health care facilities.

(g) At least every 5 years, the Illinois Fire Service Institute shall review and, if appropriate, revise or add trainings developed under this Section to incorporate new best practices, technologies, developments, or information that improves emergency response and treatment for carbon dioxide releases.

(h) At least every 5 years, the owner or operator, in coordination with local emergency response personnel, the Illinois Emergency Management Agency and Office of Homeland Security, and the Department of Public Health, shall review and, if appropriate, update emergency preparedness materials and trainings for residents and local businesses identified in subsections (c) and (d) to incorporate new best practices, technologies, developments, or information that may assist local residents and businesses to be prepared if a carbon dioxide release occurs.

(Source: P.A. 103-651, eff. 7-18-24.)

(220 ILCS 5/Art. V heading) ARTICLE V. DUTIES OF PUBLIC UTILITIES ACCOUNTS AND REPORTS

(220 ILCS 5/5-101) (from Ch. 111 2/3, par. 5-101)

Sec. 5-101. Every public utility shall furnish to the Commission all information required by it to carry into effect the provisions of this Act, and shall make specific answers to all questions submitted by the Commission.

Any public utility receiving from the Commission any blanks with directions to fill the same, shall cause the same to be properly filled out so as to answer fully and correctly each question therein propounded, and in case it is unable to answer any question, it shall give a good and sufficient reason for such failure; and said answer shall be verified under oath by the president, secretary, superintendent or general manager of such public utility and returned to the Commission at its office within the period fixed by the Commission.

Whenever required by the Commission, every public utility shall deliver to the Commission, any or all maps, profiles, reports, documents, books, accounts, papers and records in its possession, or in any way relating to its property or affecting its business, and inventories of its property, in such form as the Commission may direct, or verified copies of any or all of the same.

Every public utility shall obey and comply with each and every requirement of this Act and every order, decision, direction, rule or regulation made or prescribed by the Commission in the matters herein specified, or any other matter in any way relating to or affecting its business as a public utility, and shall do everything necessary or proper in order to secure compliance with and observance of this Act and every such order, decision, direction, rule or regulation by all of its officers, agents and employees.

(Source: P.A. 84-617.)

(220 ILCS 5/5-102) (from Ch. 111 2/3, par. 5-102)

Sec. 5-102. The Commission shall have power to establish a uniform system of accounts to be kept by public utilities or to classify public utilities and to establish a uniform system of accounts for each class and to prescribe the manner in which such accounts shall be kept. It may also, in its discretion, prescribe the forms of accounts to be kept by public utilities, including records of service, as well as accounts of earnings and expenses, and any other forms, records and memoranda which in the judgment of the Commission may be necessary to carry out any of the provisions of this Act. Where the Commission has prescribed the forms of accounts to be kept by any public utility for any of its business, it shall thereafter be unlawful for such public utility to keep any accounts for such business other than those prescribed or approved by the Commission, or those prescribed by or under the authority of any other state or of the United States.

The Commission may, from time to time, alter, amend or repeal, in whole or in part, any uniform system of accounts, or the form and manner of keeping accounts.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/5-103) (from Ch. 111 2/3, par. 5-103)

Sec. 5-103. Such systems of accounts shall provide for forms showing all sources of incomes, the amounts due and received from each source and the amounts expended and due for each purpose, distinguishing clearly all payments for operating expenses from those for new construction, extensions and additions and for balance sheets showing assets and liabilities and various forms of proprietary interest.

(Source: P.A. 84-617.)

(220 ILCS 5/5-104) (from Ch. 111 2/3, par. 5-104)

Sec. 5-104. Depreciation accounts.

(a) The Commission shall have power, after hearing, to require any or all public utilities, except electric public utilities, to keep such accounts as will adequately reflect depreciation, obsolescence and the progress of the arts. The Commission may, from time to time, ascertain and determine and by order fix the proper and adequate rate of depreciation of the several classes of property for each public utility; and each public utility shall conform its depreciation accounts to the rates so ascertained, determined and fixed.

(b) The Commission shall have the power, after hearing, to require any or all electric public utilities to keep such accounts as will adequately reflect depreciation, obsolescence, and the progress of the arts. The Commission may, from time to time, ascertain and determine and by order fix the proper and adequate rate of depreciation of the several classes of property for each electric public utility; and each electric public utility shall thereafter, absent further order of the Commission, conform its depreciation accounts to the rates so ascertained, determined and fixed until at least the end of the first full calendar year following the date of such determination.

(c) An electric public utility may from time to time alter the annual rates of depreciation, which for purposes of this subsection (c) and subsection (d) shall include amortization, that it applies to its several classes of assets so long as the rates are consistent with generally accepted accounting principles. The electric public utility shall file a statement with the Commission which shall set forth the new rates of depreciation and which shall contain a certification by an independent certified public accountant that the new rates of depreciation are consistent with generally accepted accounting principles. Upon the filing of such statement, the new rates of depreciation shall be deemed to be approved by the Commission as the rates of depreciation to be applied thereafter by the public utility as though an order had been entered pursuant to subsection (b).

(d) In any proceeding conducted pursuant to Section 9-201 or 9-202 to set an electric public utility's rates for service, the Commission may determine not to use, in determining the depreciation expense component of the public utility's rates for service, the rates of depreciation established pursuant to subsection (c), if the Commission in that proceeding finds based on the record that different rates of depreciation are required to adequately reflect depreciation, obsolescence and the progress of the arts, and fixes by order and uses for purposes of that proceeding new rates of depreciation to be thereafter employed by the electric public utility until the end of the first full calendar year following the date of the determination and thereafter until altered in accordance with subsection (b) or (c) of this Section.

(e) A gas public utility serving more than 1,600,000 customers as of January 1, 2013 may from time to time alter the annual rates of depreciation, which for purposes of this subsection (e) shall include amortization, that the gas public utility applies to its several classes of assets so long as the rates are consistent with generally accepted accounting principles. The gas public utility shall file testimony with the Commission setting forth the new rates of depreciation that shall include: (i) a summary of the causes for the change in depreciation rates; (ii) a certification by an independent certified public accountant that the new rates of depreciation are consistent with generally accepted accounting principles; (iii) the depreciation study; and (iv) the expected impact on depreciation expense from the new depreciation rates. The gas public utility shall also simultaneously submit to the Commission all work papers that support the filed depreciation study. No later than 120 days after the filing by the gas public utility under this subsection (e), the Commission shall ascertain and determine and, by order, fix the proper and adequate rate of depreciation of the several classes of property for the gas public utility. The gas public utility shall conform its depreciation accounts to the rates so ascertained, determined, and fixed. Rates of depreciation established by the Commission pursuant to this subsection (e) shall become effective upon the date of the gas public utility's filing.

(Source: P.A. 98-473, eff. 8-16-13.)

(220 ILCS 5/5-105) (from Ch. 111 2/3, par. 5-105)

Sec. 5-105. The Commission may provide for the examination and audit of all accounts, and all items shall be allocated to the accounts in the manner prescribed by the Commission. The officers and employees of the Commission shall have authority under the direction of the Commission to inspect and examine any and all books, accounts, papers, records and memoranda kept by such public utilities.

(Source: P.A. 84-617.)

(220 ILCS 5/5-106) (from Ch. 111 2/3, par. 5-106)

(Text of Section before amendment by P.A. 103-716)

Sec. 5-106. Each public utility shall have an office in one of the cities, villages or incorporated towns in this State in which its property or some part thereof is located, and shall keep in said office all such books, accounts, papers, records and memoranda as shall be ordered by the Commission to be kept within the State. The address of such office shall be filed with the Commission. No books, accounts, papers, records or memoranda ordered by the Commission to be kept within the State shall be at any time removed from the State, except upon such conditions as may be prescribed by the Commission.

Each public utility shall be liable for, and upon proper invoice from the Commission shall promptly reimburse the Commission for, the reasonable costs and expenses associated with the audit or inspection of any books, accounts, papers, records and memoranda kept outside the State.

(Source: P.A. 84-617.)

(Text of Section after amendment by P.A. 103-716)

Sec. 5-106. Each public utility shall have an office in one of the cities, villages or incorporated towns in this State in which its property or some part thereof is located, and shall keep in said office all such books, accounts, papers, records and memoranda as shall be ordered by the Commission to be kept within the State. The address of such office shall be filed with the Commission. No books, accounts, papers, records or memoranda ordered by the Commission to be kept within the State shall be at any time removed from the State, except upon such conditions as may be prescribed by the Commission.

Each public utility shall be liable for, and upon proper invoice from the Commission shall promptly reimburse the Commission for, the reasonable costs and expenses associated with the audit or inspection of any books, accounts, papers, records and memoranda kept outside the State.

In the case of a public utility that provides drinking water services, upon the request of a municipal wastewater agency or unit of local government organized under the Sanitary District Act of 1907, the North Shore Water Reclamation District Act, the Sanitary District Act of 1917, the Metropolitan Water Reclamation District Act, the Sanitary District Act of 1936, the Metro-East Sanitary District Act of 1974, or the Eastern Will Sanitary District Act, such public utility shall provide timely and accurate water usage data, in a format identifiable to the requester, for purposes of calculating wastewater billings. The public utility shall be entitled to collect its reasonable costs incurred to provide such data.

(Source: P.A. 103-716, eff. 1-1-25.)

(220 ILCS 5/5-107) (from Ch. 111 2/3, par. 5-107)

Sec. 5-107. Any person who shall wilfully make any false entry in the accounts, or in any record or memoranda or by any other means or device falsify the record of any such account, record or memoranda, or who shall willfully neglect or fail to make full, true, and correct entries in such accounts, records, or memoranda of all facts in transactions appertaining to the business of the public utility, or shall keep any accounts or record other than those prescribed or approved by the Commission, shall be guilty of a Class A misdemeanor.

If any such books, accounts, records or memoranda shall have been preserved for a period of at least three years, a public utility may with the consent of the Commission destroy such of them as in the judgment of the Commission may properly be destroyed.

(Source: P.A. 84-617.)

(220 ILCS 5/5-108) (from Ch. 111 2/3, par. 5-108)

Sec. 5-108. Any officer or employee of the Commission who divulges any fact or information coming to his knowledge during the course of an inspection, examination or investigation of any account, record, memorandum, book or paper of a public utility, except in so far as he may be authorized by the Commission or by a circuit court, shall be guilty of a Class A misdemeanor.

(Source: P.A. 84-617.)

(220 ILCS 5/5-109) (from Ch. 111 2/3, par. 5-109)

Sec. 5-109. Reports; false reports; penalty. Each public utility in the State, other than a commercial mobile radio service provider, shall each year furnish to the Commission, in such form as the Commission shall require, annual reports as to all the items mentioned in the preceding Sections of this Article, and in addition such other items, whether of a nature similar to those therein enumerated or otherwise, as the Commission may prescribe. Such annual reports shall contain all the required information for the period of 12 months ending on June 30 in each year, or ending on December 31 in each year, as the Commission may by order prescribe for each class of public utilities, except commercial mobile radio service providers, and shall be filed with the Commission at its office in Springfield within 3 months after the close of the year for which the report is made. The Commission shall have authority to require any public utility to file monthly reports of earnings and expenses of such utility, and to file other periodical or special, or both periodical and special reports concerning any matter about which the Commission is authorized by law to keep itself informed. All reports shall be under oath.

When any report is erroneous or defective or appears to the Commission to be erroneous or defective, the Commission may notify the public utility to amend such report within 30 days, and before or after the termination of such period the Commission may examine the officers, agents, or employees, and books, records, accounts, vouchers, plant, equipment and property of such public utility, and correct such items in the report as upon such examination the Commission may find defective or erroneous.

All reports made to the Commission by any public utility and the contents thereof shall be open to public inspection, unless otherwise ordered by the Commission. Such reports shall be preserved in the office of the Commission.

Any public utility which fails to make and file any report called for by the Commission within the time specified; or to make specific answer to any question propounded by the Commission within 30 days from the time it is lawfully required to do so, or within such further time, not to exceed 90 days, as may in its discretion be allowed by the Commission, shall forfeit up to $100 for each and every day it may so be in default if the utility collects less than $100,000 annually in gross revenue; and if the utility collects $100,000 or more annually in gross revenue, it shall forfeit $1,000 per day for each and every day it is in default.

Any person who willfully makes any false return or report to the Commission or to any member, officer, or employee thereof, any person who willfully, in a return or report, withholds or fails to provide material information to which the Commission is entitled under this Act and which information is either required to be filed by statute, rule, regulation, order, or decision of the Commission or has been requested by the Commission, and any person who willfully aids or abets such person shall be guilty of a Class A misdemeanor.

(Source: P.A. 95-331, eff. 8-21-07.)

(220 ILCS 5/5-110)

Sec. 5-110. Disclosure of customer information to law enforcement agencies. A public utility shall not disclose customer record information to a law enforcement agency unless the law enforcement agency requests the customer record information in writing, specifying that the information is necessary for a law enforcement purpose. Customer record information includes, but is not limited to, social security numbers, public aid numbers, and employment data. Nothing in this Section shall affect the Commission's access to information under this Act or any other law.

(Source: P.A. 90-727, eff. 8-7-98.)

(220 ILCS 5/5-111)

Sec. 5-111. Natural gas performance reporting.

(a) The General Assembly recognizes that for well over a century Illinois residents and businesses have relied on the natural gas utility system. The General Assembly finds that in order for a natural gas utility to provide safe, reliable, and affordable service to the State's current and future utility customers, a utility must refurbish, rebuild, modernize, and expand its infrastructure and adequately train its workforce on appropriate operations procedures and policies designed to effectively maintain its infrastructure.

(b) A natural gas public utility shall report annually to the Commission the following information, compiled on a calendar-year basis, beginning with the first report on April 1, 2014:

(1) the number of emergency calls with response times exceeding both 30 minutes and 60 minutes and the number of emergency calls in which the utility stopped the flow of natural gas on the system or appropriately vented natural gas in a time exceeding both 60 minutes and 90 minutes;

(2) the number of incidents of damage per thousand gas facility locate requests to the utility's pipeline facilities resulting from utility error and the number of incidents of damage per thousand gas facility locate requests to the utility's pipeline facilities resulting from the fault of third parties;

(3) the number of scheduled cathodic protection readings below -0.850 volts;

(4) the number of service lines that were inactive for over 3 years and not disconnected from a source of supply;

(5) the number of difficult to locate services replaced;

(6) the number of remotely-readable cathodic protection devices;

(7) the miles of main and numbers of services replaced that were constructed of cast iron, wrought iron, ductile iron, unprotected coated steel, unprotected bare steel, mechanically coupled steel, copper, Cellulose Acetate Butyrate (CAB) plastic, pre-1973 DuPont Aldyl "A" polyethylene, PVC, or other types of materials identified by a State or federal governmental agency as being prone to leakage;

(8) the number of miles of transmission facilities on which maximum allowable operating pressures have been established;

(9) the number of miles of transmission facilities equipped with remotely controlled shut-off valve capability; and

(10) the value in dollars of contracts in force with minority-owned, female-owned, and qualified service-disabled veteran-owned businesses.

(c) Reports required under this Section shall be submitted to the Commission by April 1 of each year. Reports shall be verified in the same manner as Form 21 ILCC and contain the information specified in subsection (b) of this Section for the preceding calendar year. The reports shall further identify the number of jobs attributable to each of the reporting requirements in (b)(1) through (b)(10) of this Section. Following the submission of a utility's initial report, subsequent reports by the utility shall state year-over-year changes in the information being reported. The Commission shall post the reports on the public portion of its web site.

(d) A natural gas utility shall submit an annual plan specifying its goals for each of the items identified in subsection (b) of this Section, and such utility is expected to show reasonable and continuing progress in improving its performance under the criteria identified in subsection (b) of this Section. If the Commission finds, after notice and hearing, that a utility has failed to show progressive improvement in its performance under those criteria, the Commission may require the natural gas utility to submit a remediation plan for the criteria identified in subsection (b) of this Section designed to improve the utility's performance.

(e) The Commission may adopt rules to implement the requirements of this Section.

(f) This Section does not apply to a gas utility that on January 1, 2013 provided gas service to fewer than 100,000 customers in Illinois.

(Source: P.A. 98-57, eff. 7-5-13.)

(220 ILCS 5/5-115)

Sec. 5-115. (Repealed).

(Source: P.A. 97-1041, eff. 8-20-12. Repealed by P.A. 98-1056, eff. 8-26-14.)

(220 ILCS 5/5-117)

Sec. 5-117. Supplier diversity goals.

(a) The public policy of this State is to collaboratively work with companies that serve Illinois residents to improve their supplier diversity in a non-antagonistic manner.

(b) The Commission shall require all gas, electric, and water utilities with at least 100,000 customers under its authority to submit an annual report by April 15, 2015 and every April 15 thereafter, in a searchable Adobe PDF format, on all procurement goals and actual spending for female-owned, minority-owned, veteran-owned, and small business enterprises in the previous calendar year. These goals shall be expressed as a percentage of the total work performed by the entity submitting the report, and the actual spending for all female-owned, minority-owned, veteran-owned, and small business enterprises shall also be expressed as a percentage of the total work performed by the entity submitting the report.

(c) Each participating company in its annual report shall include the following information:

(1) an explanation of the plan for the next year to increase participation;

(2) an explanation of the plan to increase the goals;

(3) the areas of procurement each company shall be actively seeking more participation in the next year;

(3.5) a buying plan for the specific goods and services the company intends to buy in the next 6 to 18 months, that is either (i) organized by and reported at the level of each applicable North American Industry Classification System code, (ii) provided using a method, system, or description similar to the North American Industry Classification System, or (iii) provided using the major categories of goods and related services utilized in the company's procurement system, and including any procurement codes used by the company, to assist entrepreneurs and diverse companies to understand upcoming opportunities to work with the company, however, a utility shall not be required to include commercially-sensitive data, nonpublic procurement information, or other information that could compromise a utility's ability to negotiate the most advantageous price or terms;

(4) an outline of the plan to alert and encourage potential vendors in that area to seek business from the company;

(5) an explanation of the challenges faced in finding quality vendors and offer any suggestions for what the Commission could do to be helpful to identify those vendors;

(6) a list of the certifications the company recognizes;

(7) the point of contact for any potential vendor who wishes to do business with the company and explain the process for a vendor to enroll with the company as a minority-owned, women-owned, or veteran-owned company; and

(8) any particular success stories to encourage other companies to emulate best practices.

(d) Each annual report shall include as much State-specific data as possible. If the submitting entity does not submit State-specific data, then the company shall include any national data it does have and explain why it could not submit State-specific data and how it intends to do so in future reports, if possible.

(e) Each annual report shall include the rules, regulations, and definitions used for the procurement goals in the company's annual report.

(f) The Commission and all participating entities shall hold an annual workshop open to the public in 2015 and every year thereafter on the state of supplier diversity to collaboratively seek solutions to structural impediments to achieving stated goals, including testimony from each participating entity as well as subject matter experts and advocates. The Commission shall publish a database on its website of the point of contact for each participating entity for supplier diversity, along with a list of certifications each company recognizes from the information submitted in each annual report. The Commission shall publish each annual report on its website and shall maintain each annual report for at least 5 years.

(Source: P.A. 102-558, eff. 8-20-21; 102-662, eff. 9-15-21; 102-673, eff. 11-30-21; 102-1031, eff. 5-27-22.)

(220 ILCS 5/5-201) (from Ch. 111 2/3, par. 5-201)

Sec. 5-201. In case any public utility shall do, cause to be done or permit to be done any act, matter or thing prohibited, forbidden or declared to be unlawful, or shall omit to do any act, matter or thing required to be done either by any provisions of this Act or any rule, regulation, order or decision of the Commission, issued under authority of this Act, the public utility shall be liable to the persons or corporations affected thereby for all loss, damages or injury caused thereby or resulting therefrom, and if the court shall find that the act or omission was wilful, the court may in addition to the actual damages, award damages for the sake of example and by the way of punishment. An action to recover for such loss, damage or injury may be brought in the circuit court by any person or corporation.

In every case of a recovery of damages by any person or corporation under the provisions of this Section, the plaintiff shall be entitled to a reasonable attorney's fee to be fixed by the court, which fee shall be taxed and collected as part of the costs in the case.

No recovery as in this Section provided shall in any manner affect a recovery by the State of the penalties in this Act provided.

(Source: P.A. 84-617.)

(220 ILCS 5/5-202) (from Ch. 111 2/3, par. 5-202)

Sec. 5-202. Violations; penalty. Any public utility, any corporation other than a public utility, or any person acting as a public utility, that violates or fails to comply with any provisions of this Act or that fails to obey, observe, or comply with any order, decision, rule, regulation, direction, or requirement, or any part or provision thereof, of the Commission, made or issued under authority of this Act, in a case in which a penalty is not otherwise provided for in this Act, shall be subject to a civil penalty imposed in the manner provided in Section 4-203. A small public utility, as defined in subsection (b) of Section 4-502 of this Act, is subject to a civil penalty of not less than $500 nor more than $2,000 for each and every offense. All other public utilities, corporations other than a public utility, and persons acting as a public utility are subject to a civil penalty of up to $30,000 for each and every offense, except as provided in this Section and in Sections 13-101, 13-304, 13-305, and 5-202.1 of this Act.

Every violation of the provisions of this Act or of any order, decision, rule, regulation, direction, or requirement of the Commission, or any part or portion thereof, by any corporation or person, is a separate and distinct offense, provided, however, that if the same act or omission violates more than one provision of this Act, or of any order, decision, rule, regulation, direction, or requirement of the Commission, only one penalty or cumulative penalty may be imposed for such act or omission. In case of a continuing violation, each day's continuance thereof shall be a separate and distinct offense, provided, however, that the cumulative penalty for any continuing violation shall not exceed $500,000, except in the case of a small utility, as defined in subsection (b) of Section 4-502 of this Act, in which case the cumulative penalty for any continuing violation shall not exceed $35,000, and provided further that these limits shall not apply where the violation was intentional and either (i) created substantial risk to the safety of the utility's employees or customers or the public or (ii) was intended to cause economic benefits to accrue to the violator.

In construing and enforcing the provisions of this Act relating to penalties, the act, omission, or failure of any officer, agent, or employee of any public utility, corporation other than a public utility, or person acting as a public utility, that is acting within the scope of his official duties or employment, shall in every case be deemed to be the act, omission, or failure of such public utility, corporation other than a public utility, or person acting as a public utility.

If the party who has violated or failed to comply with this Act or an order, decision, rule, regulation, direction, or requirement of the Commission, or any part or provision thereof, fails to seek timely review pursuant to Sections 10-113 and 10-201 of this Act, the party shall, upon expiration of the statutory time limit, be subject to the civil penalty provision of this Section.

No penalties shall accrue under this provision until 15 days after the mailing of a notice to such party or parties that they are in violation of or have failed to comply with the Act or order, decision, rule, regulation, direction, or requirement of the Commission or any part or provision thereof, except that this notice provision shall not apply when the violation was intentional.

(Source: P.A. 93-457, eff. 8-8-03.)

(220 ILCS 5/5-202.1)

Sec. 5-202.1. Misrepresentation before Commission; penalty.

(a) Any person or corporation, as defined in Sections 3-113 and 3-114 of this Act, who knowingly misrepresents facts to the Commission in response to any Commission contact, inquiry or discussion or knowingly aids another in doing so in response to any Commission contact, inquiry or discussion or knowingly permits another to misrepresent facts through testimony or the offering or withholding of material information in any proceeding shall be subject to a civil penalty. Whenever the Commission is of the opinion that a person or corporation is misrepresenting or has misrepresented facts, the Commission may initiate a proceeding to determine whether a misrepresentation has in fact occurred. If the Commission finds that a person or corporation has violated this Section, the Commission shall impose a penalty of not less than $1,000. Each misrepresentation of a fact found by the Commission shall constitute a separate and distinct violation. In determining the amount of the penalty to be assessed, the Commission may consider any matters of record in aggravation or mitigation of the penalty, as set forth in Section 4-203, including but not limited to the following:

(1) the presence or absence of due diligence on the part of the violator in attempting to comply with the Act;

(2) any economic benefits accrued, or expected to be accrued, by the violator because of the misrepresentation; and

(3) the amount of monetary penalty that will serve to deter further violations by the violator and to otherwise aid in enhancing voluntary compliance with the Act.

(b) Any action to enforce civil penalties arising under this Section shall be undertaken pursuant to Section 4-203.

(c) For purposes of this Section, "Commission," as defined in Section 3-102, refers to any Commissioner, agent, or employee of the Illinois Commerce commission, and also refers to any other person engaged to represent the Commission in carrying out its regulatory or law enforcement obligations.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/5-203) (from Ch. 111 2/3, par. 5-203)

Sec. 5-203. Every person who, either individually, or acting as an officer, agent, or employee of a public utility or of a corporation other than a public utility, violates or fails to comply with any provisions of this Act, or fails to observe, obey or comply with any order, decision, rule, regulation, direction or requirement, or any part or portion thereof, of the Commission, made or issued under authority of this Act, or who procures, aids or abets any public utility in its violation of this Act or in its failure to obey, observe or comply with this Act or any such order, decision, rule, regulation, direction, or requirement, or any part or portion thereof, in a case in which a penalty is not otherwise provided for in this Act, is guilty of a Class A misdemeanor.

(Source: P.A. 84-617.)

(220 ILCS 5/Art. VI heading) ARTICLE VI. CAPITALIZATION

(220 ILCS 5/6-101) (from Ch. 111 2/3, par. 6-101)

Sec. 6-101. The power of public utilities to issue stocks, stock certificates, bonds, notes and other evidences of indebtedness and to create liens on their property is a special privilege, the right of supervision, regulation, restriction and control of which is and shall continue to be vested in the State, and such power shall be exercised by the Commission hereby created according to the provisions of this Act and under such rules and regulations as the Commission may prescribe.

The Commission shall provide, by serial number or other device to be placed on the face thereof, for the proper and easy identification of such stocks, stock certificates, bonds, notes and other evidences of indebtedness as may be issued by public utilities under the provisions of this article.

(Source: P.A. 84-617.)

(220 ILCS 5/6-102) (from Ch. 111 2/3, par. 6-102)

Sec. 6-102. Authorization of issues of stock.

(a) Subject to the provisions of this Act and of the order of the Commission issued as provided in this Act, a public utility may issue stocks and stock certificates, and bonds, notes and other evidences of indebtedness payable at periods of more than 12 months after the date thereof for any lawful purpose. However, such public utility shall first have secured from the Commission an order authorizing such issue and stating the amount thereof and the purpose or purposes to which the issue or the proceeds thereof are to be applied, and that in the opinion of the Commission, the money, property or labor to be procured or paid for by such issue is reasonably required for the purpose or purposes specified in the order.

(b) The provisions of this subsection (b) shall apply only to (1) any issuances of stock in a cumulative amount, exclusive of any issuances referred to in item (3), that are 10% or more in a calendar year or 20% or more in a 24-month period of the total common stockholders' equity or of the total amount of preferred stock outstanding, as the case may be, of the public utility, and (2) to any issuances of bonds, notes or other evidences of indebtedness in a cumulative principal amount, exclusive of any issuances referred to in item (3), that are 10% or more in a calendar year or 20% or more in a 24-month period of the aggregate principal amount of bonds, notes and other evidences of indebtedness of the public utility outstanding, all as of the date of the issuance, but shall not apply to (3) any issuances of stock or of bonds, notes or other evidences of indebtedness 90% or more of the proceeds of which are to be used by the public utility for purposes of refunding, redeeming or refinancing outstanding issues of stock, bonds, notes or other evidences of indebtedness. To enable it to determine whether it will issue the order required by subsection (a) of this Section, the Commission may hold a hearing and may make such additional inquiry or investigation, and examine such witnesses, books, papers, accounts, documents and contracts and require the filing of such data as it may deem of assistance. The public utility may be required by the Commission to disclose every interest of the directors of such public utility in any transaction under investigation. The Commission shall have power to investigate all such transactions and to inquire into the good faith thereof, to examine books, papers, accounts, documents and contracts of public utilities, construction or other companies or of firms or individuals with whom the public utility shall have had financial transactions, for the purpose of enabling it to verify any statements furnished, and to examine into the actual value of property acquired by or services rendered to such public utility. Before issuing its order, the Commission, when it is deemed necessary by the Commission, shall make an adequate physical valuation of all property of the public utility, but a valuation already made under proper public supervision may be adopted, either in whole or in part, at the discretion of the Commission; and shall also examine all previously authorized or outstanding securities of the public utility, and fixed charges attached thereto. A statement of the results of such physical valuation, and a statement of the character of all outstanding securities, together with the conditions under which they are held, shall be included in the order. The Commission may require that such information or such part thereof as it thinks proper, shall appear upon the stock, stock certificate, bond, note or other evidence of indebtedness authorized by its order. The Commission may by its order grant permission for the issue of such stock certificates, or bonds, notes or other evidences of indebtedness in the amount applied for, or in a lesser amount, or not at all, and may attach to the exercise of its permission such condition or conditions as it may deem reasonable and necessary. Nothing in this Section shall prevent a public utility from seeking, nor the Commission from approving, a shelf registration plan for issuing securities over a reasonable period in accordance with regulations established by the United States Securities and Exchange Commission. Any securities issued pursuant to an approved shelf registration plan need not be further approved by the Commission so long as they are in compliance with the approved shelf registration plan. The Commission shall have the power to refuse its approval of applications to issue securities, in whole or in part, upon a finding that the issue of such securities would be contrary to public interest. The Commission may also require the public utility to compile for the information of its shareholders such facts in regard to its financial transactions, in such form as the Commission may direct.

No public utility shall, without the consent of the Commission, apply the issue of any stock or stock certificates, or bond, note or other evidence of indebtedness, which was issued pursuant to an order of the Commission entered pursuant to this subsection (b), or any part thereof, or any proceeds thereof, to any purpose not specified in the Commission's order or to any purpose specified in the Commission's order in excess of the amount authorized for such purpose; or issue or dispose of the same on any terms less favorable than those specified in such order, or a modification thereof. The Commission shall have the power to require public utilities to account for the disposition of the proceeds of all sales of stocks and stock certificates, and bonds, notes and other evidences of indebtedness, which were issued pursuant to an order of the Commission entered pursuant to this subsection (b), in such form and detail as it may deem advisable, and to establish such rules and regulations as it may deem reasonable and necessary to insure the disposition of such proceeds for the purpose or purposes specified in its order.

(c) A public utility may issue notes, for proper purposes, and not in violation of any provision of this Act or any other Act, payable at periods of not more than 12 months after the date of issuance of the same, without the consent of the Commission; but no such note shall, in whole or in part, be renewed or be refunded from the proceeds of any other such note or evidence of indebtedness from time to time without the consent of the Commission for an aggregate period of longer than 2 years. A "telecommunications carrier" as that term is defined by Section 13-202 of this Act is exempt from the requirements of this subsection (c).

(d) Any issuance of stock or of bonds, notes or other evidences of indebtedness, other than issuances of notes pursuant to subsection (c) of this Section, which is not subject to subsection (b) of this Section, shall be regulated by the Commission as follows: the public utility shall file with the Commission, at least 15 days before the date of the issuance, an informational statement setting forth the type and amount of the issue and the purpose or purposes to which the issue or the proceeds thereof are to be applied. Prior to the date of the issuance specified in the public utility's filing, the Commission, if it finds that the issuance is not subject to subsection (b) of this Section, shall issue a written order in conformance with subsection (a) of this Section authorizing the issuance. Notwithstanding any other provisions of this Act, the Commission may delegate its authority to enter the order required by this subsection (d) to an administrative law judge.

(e) The Commission shall have no power to authorize the capitalization of the right to be a corporation, or to authorize the capitalization of any franchise, license, or permit whatsoever or the right to own, operate or enjoy any such franchise, license, or permit, in excess of the amount (exclusive of any tax or annual charge) actually paid to the State or to a political subdivision thereof as the consideration for the grant of such franchise, license, permit or right; nor shall any contract for consolidation or lease be capitalized, nor shall any public utility hereafter issue any bonds, notes or other evidences of indebtedness against or as a lien, upon any contract for consolidation or merger.

(f) The provisions of this Section shall not apply to public utilities which are not corporations duly incorporated under the laws of this State to the extent that any such public utility may issue stock, bonds, notes or other evidences of indebtedness not directly or indirectly constituting or creating a lien or charge on, or right to profits from, any property used or useful in rendering service within this State.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/6-103) (from Ch. 111 2/3, par. 6-103)

Sec. 6-103. The capitalization of a public utility formed by a merger or consolidation of two or more corporations shall be subject to the approval of the Commission, but in no event shall the Commission approve a capitalization exceeding the sum of the capital stock of the corporations so consolidated, at the par value thereof, and any additional sum actually paid in cash for improvements; nor shall any contract for consolidation or lease be capitalized in the stock of any corporation whatever; nor shall any corporation hereafter issue any bonds against or as a lien upon any contract for consolidation or merger. In any reorganization of a public utility, resulting from forced sale, or in any other manner, the amount of capitalization, including therein all stocks and stock certificates and bonds, notes and other evidences of indebtedness, shall be such as is authorized by the Commission, which in making its determination, shall not exceed the fair value of the property involved. Issuance of stocks and stock certificates, and bonds, notes or other evidences of indebtedness in connection with any consolidation, merger, or reorganization shall be subject to all the terms of Sections 6-101 and 6-102 of this Act.

(Source: P.A. 84-617.)

(220 ILCS 5/6-104) (from Ch. 111 2/3, par. 6-104)

Sec. 6-104. All stock and every stock certificate, and every bond, note or other evidence of indebtedness, of a public utility, not payable within twelve months issued without an order of the Commission authorizing the same then in effect shall be void, unless issued upon the authority of any articles of incorporation or amendments thereto, and of a vote of the stockholders or directors, filed and taken before January 1, 1914, and likewise all stock and every stock certificate, and every bond, note or other evidence of indebtedness of a public utility not payable within 12 months, issued with the authorization of the Commission, but not conforming in its provisions to the provisions, if any, which it is required by the order of authorization of the Commission to contain, shall be void; but no failure in any other respect to comply with the terms or conditions of the order of authorization of the Commission shall render void any stock or stock certificate, or any bond, note or other evidence of indebtedness, except as to a corporation or person taking the same with notice of the failure to comply with the order of the Commission.

(Source: P.A. 84-617.)

(220 ILCS 5/6-105) (from Ch. 111 2/3, par. 6-105)

Sec. 6-105. Every public utility which, directly or indirectly, issues or causes to be issued, any stock, stock certificate, bond, note or other evidence of indebtedness, in non-conformity with the order of the Commission authorizing the same, or contrary to the provisions of this Act, or which applies the proceeds from the sale thereof, or any part thereof, to any purpose other than the purpose or purposes specified in the Commission's order, as herein provided, or to any purpose specified in the Commission's order in excess of the amount authorized for such purpose, shall be guilty of a business offense and shall be subject to a penalty of not less than $500 nor more than $20,000 for each offense.

(Source: P.A. 84-617.)

(220 ILCS 5/6-106) (from Ch. 111 2/3, par. 6-106)

Sec. 6-106. Every officer, agent or employee of a public utility, and every other person who knowingly authorizes, directs, issues or executes, causes to be issued or executed, or aids in the issue or execution of any stock, stock certificate, bond, note or other evidence of indebtedness, in nonconformity with the order of the Commission authorizing the same, or contrary to the provisions of this Act; or who, in any proceeding before the Commission, knowingly makes any false statement or representation, or with the knowledge of its falsity files or causes to be filed with the Commission any false statement or representation, which said statement or representation so made, filed or cause to be filed, may tend in any way to influence the Commission to make an order authorizing the issue of any stock or stock certificate, or any bond, note or other evidence of indebtedness, or which results in procuring from the Commission the making of any such order, or who, with knowledge that any false statement or representation was made to the Commission, in any proceeding, tending in any way to influence the Commission to make such order, issues or executes or negotiates, or causes to be issued, executed or negotiated any such stock or stock certificate, or bond, note or other evidence of indebtedness, or who, directly or indirectly, knowingly applies, or causes or assists to be applied the proceeds or any part thereof, from the sale of any stock or stock certificate, or bond, note or other evidence of indebtedness, to any purpose not specified in the Commission's order or to any purpose specified in the Commission's order in excess of the amount authorized for such purpose, or who, with knowledge that any stock or stock certificate, or bond, note or other evidence of indebtedness, has been issued or executed in violation of any of the provisions of this Act, negotiates, or causes the same to be negotiated, shall be guilty of a Class 3 felony.

(Source: P.A. 84-617.)

(220 ILCS 5/6-107) (from Ch. 111 2/3, par. 6-107)

Sec. 6-107. No provisions of this Act, and no deed or act done or performed under or in connection therewith, shall be held or construed to obligate the State of Illinois to pay or guarantee, in any manner whatsoever, any stock or stock certificate, or bond, note or other evidence of indebtedness, authorized, issued or executed under the provisions of this Act, nor shall it be held or construed to imply any validation or approval by the State of past issues, nor that past or future or past and future issues represent actual value of property owned or to be owned by a public utility or the value of such property for rate making purposes.

(Source: P.A. 84-617.)

(220 ILCS 5/6-108) (from Ch. 111 2/3, par. 6-108)

Sec. 6-108. The Commission shall charge every public utility receiving permission under this Act for the issue of stocks, bonds, notes and other evidences of indebtedness an amount equal to 12 cents for every $100 of the par or stated value of stocks, and 24 cents for every $100 of the principal amount of bonds, notes or other evidences of indebtedness, authorized by the Commission, which shall be paid to the Commission no later than 30 days after service of the Commission order authorizing the issuance of those stocks, bonds, notes or other evidences of indebtedness. Provided, that if any such stock, bonds, notes or other evidences of indebtedness constitutes or creates a lien or charge on, or right to profits from, any property not situated in this State, this fee shall be paid only on the amount of any such issue which is the same proportion of the whole issue as the property situated in this State is of the total property on which such securities issue creates a lien or charge, or from which a right to profits is established; and provided further, that no public utility shall be required to pay any fee for permission granted to it by the Commission in any of the following cases:

(1) To guarantee bonds or other securities.

(2) To issue bonds, notes or other evidences of indebtedness issued for the purpose of converting, exchanging, taking over, refunding, discharging or retiring any bonds, notes or other evidences of indebtedness except:

(a) When issued for an aggregate period of longer than 2 years for the purpose of converting, exchanging, taking over, refunding, discharging or retiring any note, or renewals thereof, issued without the consent of the State Public Utilities Commission of Illinois or the Public Utilities Commission or the Illinois Commerce Commission; or

(b) When issued for the purpose of converting, exchanging, taking over, refunding, discharging or retiring bonds, notes or other evidences of indebtedness issued prior to January 1, 1914, and upon which no fee has been previously paid.

(3) To issue shares of stock upon the conversion of convertible bonds, notes or other evidences of indebtedness or upon the conversion of convertible stock of another class in accordance with a conversion privilege contained in such convertible bonds, notes or other evidences of indebtedness or contained in such convertible stock, as the case may be, where a fee (in the amount payable under this Section in the case of evidences of indebtedness) has been previously paid for the issuance of such convertible bonds, notes or other evidences of indebtedness, or where a fee (in the amount payable under this Section in the case of stocks) has been previously paid for the issuance of such convertible stock, or where such convertible stock was issued prior to July 1, 1951 and upon which no fee has been previously paid, as the case may be.

(4) To issue shares of stocks for the purpose of redeeming or otherwise retiring, or in exchange for, other stocks, where the fee for the issuance of such other stocks has been previously paid, or where such other stocks were issued prior to July 1, 1951 and upon which no fee has been previously paid, as the case may be, but only to the extent that the par or stated value of the shares of stock so issued does not exceed the par or stated value of the other stocks redeemed or otherwise retired or exchanged.

All fees collected by the Commission under this Section shall be paid within 10 days after the receipt of the same, accompanied by a detailed statement of the same, into the Public Utility Fund in the State treasury.

(Source: P.A. 93-32, eff. 7-1-03.)

(220 ILCS 5/Art. VII heading) ARTICLE VII. INTERCORPORATE RELATIONS

(220 ILCS 5/7-101) (from Ch. 111 2/3, par. 7-101)

Sec. 7-101. Transactions with affiliated interests.

(1) The Commission shall have jurisdiction over holders of the voting capital stock of all public utilities under the jurisdiction of the Commission to such extent as may be necessary to enable the Commission to require the disclosure of the identity in respective interests of every owner of any substantial interest in such voting capital stocks. One per centum or more is a substantial interest, within the meaning of this subdivision.

(2) (i) Except as provided in subparagraph (ii) of this subsection (2), the Commission shall have jurisdiction over affiliated interests having transactions, other than ownership of stock and receipt of dividends thereon, with public utilities under the jurisdiction of the Commission, to the extent of access to all accounts and records of such affiliated interests relating to such transactions, including access to accounts and records of joint or general expenses, any portion of which may be applicable to such transactions; and to the extent of authority to require such reports with respect to such transactions to be submitted by such affiliated interests, as the Commission may prescribe.

(ii) The Commission shall have jurisdiction over affiliated interests having transactions, other than ownership of stock and receipt of dividends thereon, with electric and gas public utilities under the jurisdiction of the Commission, to the extent of access to all accounts and records of such affiliated interests relating to such transactions, including access to accounts and records of joint and general expenses with the electric or gas public utility any portion of which is related to such transactions; and to the extent of authority to require such reports with respect to such transactions to be submitted by such affiliated interests, as the Commission may prescribe; provided, however, that prior to requesting such access or reports from the affiliated interest, the Commission shall first seek to obtain the information that would be included in such accounts, records or reports from the public utility. The Commission shall not have access to any accounts and records of, or require any reports from, an affiliated interest that are not related to a transaction, including without limitation a transfer or exchange of tangible or intangible assets, with the electric or gas public utility. Nothing in this paragraph shall limit the authority of the Commission otherwise provided under this Act to have access to accounts and records of, or to require reports from, the electric or gas public utility or to prescribe guidelines which the electric or gas public utility must follow in allocating costs to transactions with affiliated interests.

For the purpose of this Section, the phrase "affiliated interests" means:

(a) Every corporation and person owning or holding, directly or indirectly, 10% or more of the voting capital stock of such public utility;

(b) Every corporation and person in any chain of successive ownership of 10% or more of voting capital stock;

(c) Every corporation, 10% or more of whose voting capital stock is owned by any person or corporation owning 10% or more of the voting capital stock of such public utility, or by any person or corporation in any such chain of successive ownership of 10% or more of voting capital stock;

(d) Every corporation, 10% or more of whose voting securities is owned, directly or indirectly by such public utility;

(e) Every person who is an elective officer or director of such public utility or of any corporation in any chain of successive ownership of 10% or more of voting capital stock;

(f) Every corporation which has one or more elective officers or one or more directors in common with such public utility;

(g) Every corporation or person which the Commission may determine as a matter of fact after investigation and hearing is actually exercising any substantial influence over the policies and actions of such public utility even though such influence is not based upon stock holding, stockholders, directors or officers to the extent specified in this Section;

(h) Every person or corporation who or which the Commission may determine as a matter of fact after investigation and hearing is actually exercising such substantial influence over the policies and actions of such public utility in conjunction with one or more other corporations or persons with which or whom they are related by ownership or blood relationship or by action in concert that together they are affiliated with such public utility within the meaning of this Section even though no one of them alone is so affiliated.

No such person or corporation is affiliated within the meaning of this Section however, if such person or corporation is otherwise subject to the jurisdiction of the Commission or such person or corporation has not had transactions or dealings other than the holding of stock and the receipt of dividends thereon with such public utility during the 2 year period next preceding.

(3) No management, construction, engineering, supply, financial or similar contract and no contract or arrangement for the purchase, sale, lease or exchange of any property or for the furnishing of any service, property or thing, hereafter made with any affiliated interest, as hereinbefore defined, shall be effective unless it has first been filed with and consented to by the Commission or is exempted in accordance with the provisions of this Section or of Section 16-111 of this Act. The Commission may condition such approval in such manner as it may deem necessary to safeguard the public interest. If it be found by the Commission, after investigation and a hearing, that any such contract or arrangement is not in the public interest, the Commission may disapprove such contract or arrangement. Every contract or arrangement not consented to or excepted by the Commission as provided for in this Section is void.

The consent to, or exemption or waiver of consent to, any contract or arrangement under this Section or Section 16-111, does not constitute approval of payments thereunder for the purpose of computing expense of operation in any rate proceeding. However, the Commission shall not require a public utility to make purchases at prices exceeding the prices offered by an affiliated interest, and the Commission shall not be required to disapprove or disallow, solely on the ground that such payments yield the affiliated interest a return or rate of return in excess of that allowed the public utility, any portion of payments for purchases from an affiliated interest.

(4) The Commission may by general rules applicable alike to all public utilities affected thereby waive the filing and necessity for approval of contracts and arrangements described in subparagraph (3) of this Section in cases of (a) contracts or arrangements made in the ordinary course of business for the employment of officers or employees; (b) contracts or arrangements made in the ordinary course of business for the purchase of services, supplies, or other personal property at prices not exceeding the standard or prevailing market prices, or at prices or rates fixed pursuant to law; (c) contracts or arrangements where the total obligation to be incurred under such contract or arrangement does not exceed the lesser of (i) $5,000,000 or (ii) 2% of the public utility's receipts from all tariffed services (as defined in Article XVI) in the preceding calendar year; (d) the temporary leasing, lending or interchanging of equipment in the ordinary course of business or in case of an emergency; and (e) contracts made by a public utility with a person or corporation whose bid is the most favorable to the public utility, as ascertained by competitive bidding. If the Commission, after a hearing, finds that any public utility is abusing or has abused such general rule and thereby is evading compliance with the standard established herein, the Commission may require such public utility to thereafter file and receive the Commission's approval upon all such transactions, but that general rule shall remain in full force and effect as to all other public utilities.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/7-102) (from Ch. 111 2/3, par. 7-102)

Sec. 7-102. Transactions requiring Commission approval.

(A) Unless the consent and approval of the Commission is first obtained or unless such approval is waived by the Commission or is exempted in accordance with the provisions of this Section or of any other Section of this Act:

(a) No 2 or more public utilities may enter into contracts with each other that will enable such public utilities to operate their lines or plants in connection with each other.

(b) No public utility may purchase, lease, or in any other manner acquire control, direct or indirect, over the franchises, licenses, permits, plants, equipment, business or other property of any other public utility.

(c) No public utility may assign, transfer, lease, mortgage, sell (by option or otherwise), or otherwise dispose of or encumber the whole or any part of its franchises, licenses, permits, plant, equipment, business, or other property, but the consent and approval of the Commission shall not be required for the sale, lease, assignment or transfer (1) by any public utility of any tangible personal property which is not necessary or useful in the performance of its duties to the public, or (2) by any railroad of any real or tangible personal property.

(d) No public utility may by any means, direct or indirect, merge or consolidate its franchises, licenses, permits, plants, equipment, business or other property with that of any other public utility.

(e) No public utility may purchase, acquire, take or receive any stock, stock certificates, bonds, notes or other evidences of indebtedness of any other public utility.

(f) No public utility may in any manner, directly or indirectly, guarantee the performance of any contract or other obligation of any other person, firm or corporation whatsoever.

(g) No public utility may use, appropriate, or divert any of its moneys, property or other resources in or to any business or enterprise which is not, prior to such use, appropriation or diversion essentially and directly connected with or a proper and necessary department or division of the business of such public utility; provided that this subsection shall not be construed as modifying subsections (a) through (e) of this Section.

(h) No public utility may, directly or indirectly, invest, loan or advance, or permit to be invested, loaned or advanced any of its moneys, property or other resources in, for, in behalf of or to any other person, firm, trust, group, association, company or corporation whatsoever, except that no consent or approval by the Commission is necessary for the purchase of stock in development credit corporations organized under the Illinois Development Credit Corporation Act, providing that no such purchase may be made hereunder if, as a result of such purchase, the cumulative purchase price of all such shares owned by the utility would exceed one-fiftieth of one per cent of the utility's gross operating revenue for the preceding calendar year.

(B) Any public utility may present to the Commission for approval options or contracts to sell or lease real property, notwithstanding that the value of the property under option may have changed between the date of the option and the subsequent date of sale or lease. If the options or contracts are approved by the Commission, subsequent sales or leases in conformance with those options or contracts may be made by the public utility without any further action by the Commission. If approval of the options or contracts is denied by the Commission, the options or contracts are void and any consideration theretofore paid to the public utility must be refunded within 30 days following disapproval of the application.

(C) The proceedings for obtaining the approval of the Commission provided for in this Section shall be as follows: There shall be filed with the Commission a petition, joint or otherwise, as the case may be, signed and verified by the president, any vice president, secretary, treasurer, comptroller, general manager, or chief engineer of the respective companies, or by the person or company, as the case may be, clearly setting forth the object and purposes desired, and setting forth the full and complete terms of the proposed assignment, transfer, lease, mortgage, purchase, sale, merger, consolidation, contract or other transaction, as the case may be. Upon the filing of such petition, the Commission shall, if it deems necessary, fix a time and place for the hearing thereon. After such hearing, or in case no hearing is required, if the Commission is satisfied that such petition should reasonably be granted, and that the public will be convenienced thereby, the Commission shall make such order in the premises as it may deem proper and as the circumstances may require, attaching such conditions as it may deem proper, and thereupon it shall be lawful to do the things provided for in such order. The Commission shall impose such conditions as will protect the interest of minority and preferred stockholders.

(D) The Commission shall have power by general rules applicable alike to all public utilities, other than electric and gas public utilities, affected thereby to waive the filing and necessity for approval of the following: (a) sales of property involving a consideration of not more than $300,000 for utilities with gross revenues in excess of $50,000,000 annually and a consideration of not more than $100,000 for all other utilities; (b) leases, easements and licenses involving a consideration or rental of not more than $30,000 per year for utilities with gross revenues in excess of $50,000,000 annually and a consideration or rental of not more than $10,000 per year for all other utilities; (c) leases of office building space not required by the public utility in rendering service to the public; (d) the temporary leasing, lending or interchanging of equipment in the ordinary course of business or in case of an emergency; and (e) purchase-money mortgages given by a public utility in connection with the purchase of tangible personal property where the total obligation to be secured shall be payable within a period not exceeding one year. However, if the Commission, after a hearing, finds that any public utility to which such rule is applicable is abusing or has abused such general rule and thereby is evading compliance with the standard established herein, the Commission shall have power to require such public utility to thereafter file and receive the Commission's approval upon all such transactions as described in this Section, but such general rule shall remain in full force and effect as to all other public utilities to which such rule is applicable.

(E) The filing of, and the consent and approval of the Commission for, any assignment, transfer, lease, mortgage, purchase, sale, merger, consolidation, contract or other transaction by an electric or gas public utility with gross revenues in all jurisdictions of $250,000,000 or more annually involving a sale price or annual consideration in an amount of $5,000,000 or less shall not be required. The Commission shall also have the authority, on petition by an electric or gas public utility with gross revenues in all jurisdictions of $250,000,000 or more annually, to establish by order higher thresholds than the foregoing for the requirement of approval of transactions by the Commission pursuant to this Section for the electric or gas public utility, but no greater than 1% of the electric or gas public utility's average total gross utility plant in service in the case of sale, assignment or acquisition of property, or 2.5% of the electric or gas public utility's total revenue in the case of other sales price or annual consideration, in each case based on the preceding calendar year, and subject to the power of the Commission, after notice and hearing, to further revise those thresholds at a later date. In addition to the foregoing, the Commission shall have power by general rules applicable alike to all electric and gas public utilities affected thereby to waive the filing and necessity for approval of the following: (a) sales of property involving a consideration of $100,000 or less for electric and gas utilities with gross revenues in all jurisdictions of less than $250,000,000 annually; (b) leases, easements and licenses involving a consideration or rental of not more than $10,000 per year for electric and gas utilities with gross revenues in all jurisdictions of less than $250,000,000 annually; (c) leases of office building space not required by the electric or gas public utility in rendering service to the public; (d) the temporary leasing, lending or interchanging of equipment in the ordinary course of business or in the case of an emergency; and (e) purchase-money mortgages given by an electric or gas public utility in connection with the purchase of tangible personal property where the total obligation to be secured shall be payable within a period of one year or less. However, if the Commission, after a hearing, finds that any electric or gas public utility is abusing or has abused such general rule and thereby is evading compliance with the standard established herein, the Commission shall have power to require such electric or gas public utility to thereafter file and receive the Commission's approval upon all such transactions as described in this Section and not exempted pursuant to the first sentence of this paragraph or to subsection (g) of Section 16-111 of this Act, but such general rule shall remain in full force and effect as to all other electric and gas public utilities.

Every assignment, transfer, lease, mortgage, sale or other disposition or encumbrance of the whole or any part of the franchises, licenses, permits, plant, equipment, business or other property of any public utility, or any merger or consolidation thereof, and every contract, purchase of stock, or other transaction referred to in this Section and not exempted in accordance with the provisions of the immediately preceding paragraph of this Section, made otherwise than in accordance with an order of the Commission authorizing the same, except as provided in this Section, shall be void. The provisions of this Section shall not apply to any transactions by or with a political subdivision or municipal corporation of this State.

(F) The provisions of this Section do not apply to the purchase or sale of emission allowances created under and defined in Title IV of the federal Clean Air Act Amendments of 1990 (P.L. 101-549), as amended.

(Source: P.A. 90-561, eff. 12-16-97; 91-357, eff. 7-29-99.)

(220 ILCS 5/7-103) (from Ch. 111 2/3, par. 7-103)

Sec. 7-103. (1) Whenever the Commission finds that the capital of any public utility has become impaired, or will be impaired by the payment of a dividend, the Commission shall have power to order said public utility to cease and desist the declaration and payment of any dividend upon its common and preferred stock, and no such public utility shall pay any dividend upon its common and preferred stock until such impairment shall have been made good.

(2) No utility shall pay any dividend upon its common stock and preferred stock unless:

(a) The utility's earnings and earned surplus are sufficient to declare and pay same after provision is made for reasonable and proper reserves.

(b) The dividend proposed to be paid upon such common stock can reasonably be declared and paid without impairment of the ability of the utility to perform its duty to render reasonable and adequate service at reasonable rates.

(c) It shall have set aside the depreciation annuity prescribed by the Commission or a reasonable depreciation annuity if none has been prescribed.

If any dividends on common stock are proposed to be declared and paid other than as above provided, the utility shall give the Commission at least thirty days' notice in writing of its intention to so declare and pay such dividends and the Commission shall authorize the payment of such dividends only if it finds that the public interest requires such payment. Provided, however, that the Commission may grant such authority upon such conditions as it may deem necessary to safeguard the public interest.

(Source: P.A. 84-617.)

(220 ILCS 5/7-104) (from Ch. 111 2/3, par. 7-104)

Sec. 7-104. In a proceeding before the Commission in which the consent and approval of the Commission to the sale, lease or other disposition of any real property owned by a public utility is sought, any tenant in possession who has been in possession of such property for more than 5 years and who has made substantial improvements to the property has standing to appear and offer evidence to the Commission with respect to the proposed disposition, and the Commission, in making its determination, shall consider the rights and equities of such tenant in possession.

(Source: P.A. 84-617; 84-1025.)

(220 ILCS 5/7-105)

Sec. 7-105. (a) Notwithstanding anything to the contrary in Sections 6-103, 7-101, 7-102, 7-203, 7-204, and 7-204A of this Act or any rule or regulation promulgated by the Commission, a public utility providing electric service to more than 500,000 customers in this State may, within 550 days after the effective date of this amendatory Act of 1993 or any extension of time pursuant to Section 7-106 of this Act, without the approval or consent of, or prior filing for the approval or consent of, the Commission:

(i) engage in only those transactions as are reasonably necessary to create a holding company and make the public utility a subsidiary company of the holding company; and

(ii) loan to such holding company prior to the 60th day after the day on which such public utility becomes a subsidiary company of the holding company, amounts which, in the aggregate, do not exceed the lesser of $10,000,000 or 2.5% of the retained earnings of the public utility as reported on its most recent annual report to the Commission.

(b) The terms of transactions authorized by Section 7-105(a)(i) shall require that the holding company pay, or reimburse the public utility for, all expenses incurred, services rendered, or facilities provided by the public utility engaging in such transactions. Such public utility shall incur no liabilities in or in connection with such transactions other than expenses incurred to effect such transactions. The terms of any loan authorized by Section 7-105(a)(ii) shall require that the loan (i) be repaid no later than the 240th day after the public utility becomes a subsidiary company of the holding company and (ii) bear interest at the rate of 10% per annum. Contracts or arrangements between the public utility and any of its affiliates, including the holding company, other than as authorized by Section 7-105(a), shall be subject to the jurisdiction of the Commission under Sections 7-101, 7-102, 7-204A(b), and other applicable provisions, if any, of this Act.

(c) Costs incurred by a public utility in effecting or attempting to effect any transaction authorized by this Section 7-105 shall not be included in rate base or treated as allowable expenses for purposes of determining the rates to be charged by the public utility.

(d) Not later than the earlier of (i) the 30th day after a public utility or a company which seeks to become a holding company of such public utility in accordance with this Section 7-105 files any registration statement or application with any federal regulatory agency seeking authority for a transaction in which such public utility would become a subsidiary of such holding company or (ii) the 180th day after the effective date of this amendatory Act of 1993, such public utility or holding company shall file with the Commission, for the information of the Commission and the public, the information, to the extent available to such public utility or company on such day, described in Section 7-204A(a) of this Act, and such public utility or company shall, until the day on which such public utility becomes a subsidiary of a holding company, file with the Commission all additional such information, and corrections, amendments, or supplements to all previously filed such information, as soon as practicable after it becomes available to such public utility or company; provided, that nothing in this Section 7-105 eliminates or restricts the Commission's authority, on timely motion of any person or corporation, to enter an order to protect confidential, proprietary, or trade secret data or information filed with the Commission.

(e) As used in Sections 7-105 and 7-106 of this Act, "subsidiary company" and "holding company" mean a "subsidiary company" and a "holding company" as defined in the Public Utility Holding Company Act of 1935, as amended.

(Source: P.A. 88-83.)

(220 ILCS 5/7-106)

Sec. 7-106. (a) Subject to the limitations contained in this Section 7-106, and notwithstanding anything to the contrary in Section 6-103 and items (f), (g), and (h) of subsection (A) of Section 7-102 of this Act or any rule or regulation promulgated by the Commission under this Act, a public utility that has filed, pursuant to Section 7-105(d) of this Act, the information described in Section 7-204A(a) of this Act, may, without the approval or consent of, or other prior filing with, the Commission, form, invest moneys denominated in United States dollars in, and guarantee contractual obligations of a subsidiary which engages in any business that provides to persons, corporations, municipal corporations, or other entities that are customers or potential customers of the public utility (i) heating, cooling, or lighting services; (ii) energy management services; or (iii) design, development, construction, engineering, financial, maintenance, management, or consulting services for owners, lessees, managers, or operators of facilities for the generation, transmission, or distribution of electricity; each such subsidiary is referred to in this Act as a "Section 7-106 subsidiary".

(b) Prior to investing in or guaranteeing any contractual obligations of a Section 7-106 subsidiary, the utility shall file with the Commission a statement identifying all public utility assets or information in existence, such as customer lists, which the utility plans to transfer to or permit the Section 7-106 subsidiary or any associate or affiliate of the subsidiary to use, which statement shall include a description of the proposed terms and conditions under which the assets or information will be transferred or used.

(c) In any proceeding pending before the Commission to determine the rates to be charged for electric service by a public utility which has a Section 7-106 subsidiary, or which is a subsidiary of a holding company formed under Section 7-105 of this Act, the Commission shall reduce the public utility's rates to reflect the additional amount of revenue it would have earned during the test year if the Section 7-106 subsidiary, such holding company, or any other subsidiary company of such holding company had not provided the customer with the services described in items (i), (ii), and (iii) of subsection (a) of this Section. The Commission shall not reduce the revenues of the public utility unless it finds that there was no reasonable probability that the customer would have obtained the services described in items (i), (ii), and (iii) of subsection (a) of this Section from another source (including the customer), if such subsidiary, holding company, or other subsidiary company had not entered into a contract or arrangement with the customer. A written statement by an employee or authorized agent of the customer that such services are available from other sources (including the customer) and that such agent or employee believes that there was a reasonable probability that the customer would have so obtained such services from another source (including the customer) shall constitute prima facie evidence of such reasonable probability. The provisions of this subsection shall not be construed as limiting the authority of the Commission with respect to rates under any other Section of this Act.

(d) The aggregate amount of a public utility's investments in, and guarantees of, the contractual obligations of Section 7-106 subsidiaries without the approval or consent of, or prior filing with, the Commission, outstanding at the time of and after giving effect to any such investment or guarantee, shall not exceed as of the date of such investment or guarantee an amount equal to the lesser of $170,000,000 or 20% of the retained earnings of the public utility as reported on its most recent annual report to the Commission. The amount of each such guarantee shall be limited to a maximum dollar amount which shall be specified in such guarantee. The terms of each such guarantee shall provide that it shall terminate, and it shall terminate, at the time that the public utility liquidates or transfers to any entity or person, the interest and investment of such public utility in the Section 7-106 subsidiary whose obligations are subject to such guarantee. The authority of a public utility to invest in and guarantee the contractual obligations of a Section 7-106 subsidiary without the approval or consent of, or prior filing with, the Commission, as permitted by this Section 7-106, shall expire on the date such public utility liquidates or transfers its interest and investment in such Section 7-106 subsidiary.

(e) The Commission shall not consider the investment of a public utility in or its obligation to make an investment in a Section 7-106 subsidiary, or the guarantee by a public utility of contractual obligations of its Section 7-106 subsidiaries, in considering the amount or terms of any reparations or refunds to be made by such public utility to its customers.

(f) On the date that a public utility becomes a subsidiary company of a holding company pursuant to Section 7-105 of this Act, such public utility shall either:

(i) liquidate or transfer its interest and investment in its Section 7-106 subsidiaries to such holding company or to any other entity or person in a transaction which does not require the prior approval or consent of the Commission under Section 7-101 or Section 7-102 of this Act, or

(ii) file with the Commission for its approval under Section 7-101 or Section 7-102 of this Act, a plan for such public utility to liquidate or transfer its interest and investment in its Section 7-106 subsidiaries.

(g) If on the 550th day after the effective date of this amendatory Act of 1993 such public utility is not a subsidiary company of a holding company, such public utility shall on such 550th day either:

(i) liquidate or transfer its interest and investment in its Section 7-106 subsidiaries to any entity or person in a transaction which does not require the prior approval or consent of the Commission under Section 7-101 or Section 7-102 of this Act, or

(ii) file with the Commission for its approval under Section 7-101 or Section 7-102 of this Act, a plan for such public utility to liquidate or transfer its interest and investment in its Section 7-106 subsidiaries, or

(iii) file with the Commission a petition for an extension of time within which: (A) to become a subsidiary company of a holding company and to take action pursuant to subsection (f) of this Section 7-106; or (B) to take action pursuant to either subparagraph (i) or subparagraph (ii) of subsection (g) of this Section 7-106. The Commission shall grant such extension to an appropriate date unless it finds that the public utility has not taken action in a timely and appropriate manner to seek all regulatory, shareholder, and other authority for or, after obtaining all such authority, has not taken action in a timely and appropriate manner to effect a transaction in which such public utility would become a subsidiary company of a holding company. If the Commission finds that the public utility has not taken action in a timely and appropriate manner to seek all regulatory, shareholder, and other authority for or, after obtaining all such authority, has not taken action in a timely and appropriate manner to effect a transaction in which such public utility would become a subsidiary company of a holding company, the Commission shall deny the public utility's petition and shall approve a plan for such public utility to liquidate or transfer its interests and investments in its Section 7-106 subsidiaries. During the pendency of the proceeding before the Commission initiated by the petition filed by the public utility, the utility may continue to engage in activities described in Sections 7-105 and 7-106, as provided therein.

(h) Contracts or arrangements between a public utility and its Section 7-106 subsidiaries, including contracts or arrangements for any services described in Section 7-106 (a)(i), (ii), and (iii), but excluding investments and guarantees permitted by this Section 7-106, shall be subject to the jurisdiction of the Commission under Sections 7-101, 7-102, 7-204A(b), and other applicable provisions, if any, of this Act, except that such public utility may, pursuant to contracts or arrangements filed with the Commission, provide its Section 7-106 subsidiaries with office facilities or administrative and management services which are reasonably necessary for the management of the business of its Section 7-106 subsidiaries, which contracts or arrangements shall become effective upon such public utility filing with the Commission a petition seeking Commission approval thereof, and such contracts and arrangements shall remain in effect unless modified by the Commission after a hearing on such petition in which such public utility shall have the burden of proving the reasonable necessity of the provision of such facilities and services. Such contracts or arrangements shall require each Section 7-106 subsidiary to pay to the public utility the fair market value for the use of such facilities and services. The public utility shall keep its books of account and other records in a manner that will enable the Commission to determine the propriety of any allocation of costs between the public utility and its Section 7-106 subsidiaries. The burden of proving the propriety of any such allocation shall be on the public utility. The public utility shall also have the burden of proving that it has received or will receive fair market value for all facilities or services provided to its Section 7-106 subsidiaries under this Section 7-106.

(i) The costs of any public utility investment in or guarantee of the contractual obligations of its Section 7-106 subsidiaries shall not be included in rate base or treated as allowable expenses for purposes of determining the rates to be charged by the public utility.

(j) No public utility shall have any liability to any of its Section 7-106 subsidiaries, except any obligation it may have to make investments in such Section 7-106 subsidiaries in accordance with this Section 7-106. No public utility shall have any liability for any obligation or liability of any of its Section 7-106 subsidiaries, except under any guarantee of contractual obligations of such Section 7-106 subsidiaries made in accordance with this Section 7-106.

(k) No Section 7-106 subsidiary shall engage in the repair or servicing of home or other consumer appliances except in emergencies posing a threat to life or property.

(Source: P.A. 91-357, eff. 7-29-99.)

(220 ILCS 5/7-107)

Sec. 7-107. Nothing in Section 7-105 or 7-106 of this Act shall be construed as (a) limiting the ability of any public utility to engage in, or the authority of the Commission to authorize, any transaction subject to Section 7-101, 7-102, 7-204, or 7-204A of this Act as in effect prior to the effective date of this amendatory Act of 1993 or (b) affecting the validity of any petition or application for authorization under Section 7-101, 7-102, 7-204, or 7-204A of this Act pending before the Commission as of the effective date of this amendatory Act of 1993.

(Source: P.A. 88-83.)

(220 ILCS 5/7-108)

Sec. 7-108. (a) Where an affiliate of an electric public utility has offered an unregulated sale of electricity, and such affiliate would use a portion of the utility's distribution or transmission facilities to distribute or transmit the electricity that is to be so sold, the utility shall make such portion of its facilities available to any other person or entity that offers to make such sale, at the same price and under the same terms and conditions as the utility makes such portion of its facilities available to its affiliate. Nothing contained in this Section 7-108(a) shall be construed as requiring or authorizing the Commission to require an electric public utility to make any portion of its facilities available to its affiliate.

(b) Where an affiliate of a gas public utility has offered an unregulated sale of gas, and such affiliate would use a portion of the utility's distribution or transmission facilities to distribute or transmit the gas that is to be so sold, the utility shall make such portion of its facilities available to any other person or entity that offers to make such sale, at the same price and under the same terms and conditions as the utility makes such portion of its facilities available to its affiliate. Nothing contained in this Section 7-108(b) shall be construed as requiring or authorizing the Commission to require a gas public utility to make any portion of its facilities available to its affiliate.

(c) As used in this Section 7-108:

(1) The term "affiliate" shall mean (i) every corporation and person owning or holding, directly or indirectly, 10% or more of the voting capital stock of a public utility; (ii) every corporation and person in any chain of successive ownership of 10% or more of the voting capital stock of such public utility; (iii) every corporation, 10% or more of whose voting capital stock is owned by any person or corporation owning 10% or more of the voting capital stock of such public utility, or by any person or corporation in any such chain of successive ownership of 10% or more of the voting capital stock of such public utility; (iv) every entity, 10% or more of whose voting securities is owned, directly or indirectly, by such public utility or by an entity described in clauses (i), (ii), or (iii) of this paragraph; and (v) every entity in which such public utility or an entity described in clauses (i), (ii), (iii), or (iv) of this paragraph owns, controls, or holds, directly or indirectly, a financial interest entitling it or a contract right potentially entitling it to 10% or more of revenues or profits and losses of any such entity.

(2) the term "voting security" shall mean a "voting security" as defined in the Public Utility Holding Company Act of 1935, as amended, and shall also mean any security giving the owner or holder thereof the privilege to convert such security in whole or in part into a voting security, or any security directly or indirectly secured in whole or in part by the pledge of a voting security.

(3) the term "security" shall mean a "security" as defined in the Public Utility Holding Company Act of 1935, as amended.

(4) the term "unregulated sale" shall mean a sale of electricity or gas to an end-user for use in facilities in this State, the price of which sale is not regulated by the Commission.

(Source: P.A. 88-83.)

(220 ILCS 5/7-201) (from Ch. 111 2/3, par. 7-201)

Sec. 7-201. No franchise, license, permit or right to own, operate, manage or control any public utility, except common carriers engaged in interstate commerce and except telegraph or telephone companies engaged in interstate commerce, and except other public utility companies owning or operating a public utility system situated partly in Illinois and partly in an adjoining State or States, shall be hereafter granted or transferred to any grantee or transferee other than a corporation duly incorporated under the laws of this State.

No public utility shall be in any manner exempt from the provisions of this Act because or by virtue of the fact that it may be or may have been incorporated or organized under the laws of another State, or of the United States, or of a foreign country, except to the extent expressly provided herein.

(Source: P.A. 84-617.)

(220 ILCS 5/7-202) (from Ch. 111 2/3, par. 7-202)

Sec. 7-202. (Repealed).

(Source: P.A. 90-372, eff. 7-1-98. Repealed internally, eff. 7-1-98.)

(220 ILCS 5/7-203) (from Ch. 111 2/3, par. 7-203)

Sec. 7-203. No franchise, license, permit or right to own, operate, manage or control any public utility shall be assigned, transferred or leased nor shall any contract or agreement with reference to or affecting any such franchise, license, permit or right be valid or of any force or effect whatsoever, unless such assignment, lease, contract, or agreement shall have been approved by the Commission. Such permission shall not be construed to revive or validate any lapsed or invalid franchise, license, permit or right, or to enlarge or add to the powers and privileges contained in the grant of any franchise, license, permit or right, or to waive any forfeiture.

The provisions of this Section shall not apply to any transactions by or with a political subdivision or municipal corporation organized under the laws of this State.

(Source: P.A. 84-617.)

(220 ILCS 5/7-204) (from Ch. 111 2/3, par. 7-204)

Sec. 7-204. Reorganization defined; Commission approval.

(a) For purposes of this Section, "reorganization" means any transaction which, regardless of the means by which it is accomplished, results in a change in the ownership of a majority of the voting capital stock of an Illinois public utility; or the ownership or control of any entity which owns or controls a majority of the voting capital stock of a public utility; or by which 2 public utilities merge, or by which a public utility acquires substantially all of the assets of another public utility; provided, however, that "reorganization" as used in this Section shall not include a mortgage or pledge transaction entered into to secure a bona fide borrowing by the party granting the mortgage or making the pledge.

In addition to the foregoing, "reorganization" shall include for purposes of this Section any transaction which, regardless of the means by which it is accomplished, will have the effect of terminating the affiliated interest status of any entity as defined in paragraph (a), (b), (c) or (d) of subsection (2) of Section 7-101 of this Act where such entity had transactions with the public utility, in the 12 calendar months immediately preceding the date of termination of such affiliated interest status subject to subsection (3) of Section 7-101 of this Act with a value greater than 15% of the public utility's revenues for that same 12-month period. If the proposed transaction would have the effect of terminating the affiliated interest status of more than one Illinois public utility, the utility with the greatest revenues for the 12-month period shall be used to determine whether such proposed transaction is a reorganization for the purposes of this Section. The Commission shall have jurisdiction over any reorganization as defined herein.

(b) No reorganization shall take place without prior Commission approval. The Commission shall not approve any proposed reorganization if the Commission finds, after notice and hearing, that the reorganization will adversely affect the utility's ability to perform its duties under this Act. The Commission shall not approve any proposed reorganization unless the Commission finds, after notice and hearing, that:

(1) the proposed reorganization will not diminish the utility's ability to provide adequate, reliable, efficient, safe and least-cost public utility service;

(2) the proposed reorganization will not result in the unjustified subsidization of non-utility activities by the utility or its customers;

(3) costs and facilities are fairly and reasonably allocated between utility and non-utility activities in such a manner that the Commission may identify those costs and facilities which are properly included by the utility for ratemaking purposes;

(4) the proposed reorganization will not significantly impair the utility's ability to raise necessary capital on reasonable terms or to maintain a reasonable capital structure;

(5) the utility will remain subject to all applicable laws, regulations, rules, decisions and policies governing the regulation of Illinois public utilities;

(6) the proposed reorganization is not likely to have a significant adverse effect on competition in those markets over which the Commission has jurisdiction;

(7) the proposed reorganization is not likely to result in any adverse rate impacts on retail customers.

(c) The Commission shall not approve a reorganization without ruling on: (i) the allocation of any savings resulting from the proposed reorganization; and (ii) whether the companies should be allowed to recover any costs incurred in accomplishing the proposed reorganization and, if so, the amount of costs eligible for recovery and how the costs will be allocated.

(d) The Commission shall issue its Order approving or denying the proposed reorganization within 11 months after the application is filed. The Commission may extend the deadline for a period equivalent to the length of any delay which the Commission finds to have been caused by the Applicant's failure to provide data or information requested by the Commission or that the Commission ordered the Applicant to provide to the parties. The Commission may also extend the deadline by an additional period not to exceed 3 months to consider amendments to the Applicant's filing, or to consider reasonably unforeseeable changes in circumstances subsequent to the Applicant's initial filing.

(e) Subsections (c) and (d) and subparagraphs (6) and (7) of subsection (b) of this Section shall apply only to merger applications submitted to the Commission subsequent to April 23, 1997. No other Commission approvals shall be required for mergers that are subject to this Section.

(f) In approving any proposed reorganization pursuant to this Section the Commission may impose such terms, conditions or requirements as, in its judgment, are necessary to protect the interests of the public utility and its customers.

(Source: P.A. 100-840, eff. 8-13-18; 101-81, eff. 7-12-19.)

(220 ILCS 5/7-204A) (from Ch. 111 2/3, par. 7-204A)

Sec. 7-204A. (a) No Illinois public utility may reorganize as defined in Section 7-204 until the Commission has approved the application therefor. The application for approval of reorganization must at a minimum include the following information:

(1) The names and corporate relationships of all companies which are affiliated interests of the public utility on the date the public utility applies for reorganization and the name of any parent or subsidiary corporation of the public utility;

(2) A description of how the public utility plans to reorganize, including, if available at the time of application:

(i) copies of the organizational documents associated with the reorganization, including articles of incorporation or amendments to the articles of incorporation of all companies including the public utility and any affiliated interests;

(ii) copies of any filings, including securities filings, related to the reorganization made with any agency of this State or the federal government;

(3) The costs and fees attributable to the reorganization;

(4) The method by which management, personnel, property, income, losses, costs and expenses will be allocated between the public utility and any affiliated interest;

(5) A copy of any proposed agreement between the public utility and any person with which it will be an affiliated interest at the time of the application for reorganization; the application for reorganization shall be amended to provide the Commission with any proposed agreement up until the time the reorganization is approved;

(6) An identification of all public utility assets or information in existence, such as customer lists, which the applicant plans to transfer to or permit an affiliated interest to use, which identification shall include a description of the proposed terms and conditions under which the assets or information will be transferred or used; and

(7) A copy of a forecast showing the capital requirements of the public utility at the time of the proposed reorganization. The forecast shall include for each public utility on an annual basis for 5 years following the year of application:

(i) projected capital requirements;

(ii) sources of capital;

(iii) the range of the projected capital structure; and

(iv) the assumptions underlying the information included in the forecast.

(b) No public utility may permit the use of any public utility employee's services by any affiliated interest except by contract or arrangement. No public utility may sell, lease, transfer to or exchange with any affiliated interest any property except by contract or arrangement. The contract or arrangement herein is subject to Commission review at the discretion of the Commission, in the same manner as it may review any other public utility and its affiliated interest.

This Section 7-204A shall not apply to any telecommunications carrier regulated pursuant to Article XIII of this Act or to any public utility which became a subsidiary of another corporation prior to the effective date of this amendatory Act of 1989. However, this amendatory Act of 1989 may not be deemed to diminish the Commission's control and regulation over any public utility.

(Source: P.A. 86-218.)

(220 ILCS 5/7-205) (from Ch. 111 2/3, par. 7-205)

Sec. 7-205. If any public utility is engaged in carrying on any business other than that of a public utility, which other business is not otherwise subject to the jurisdiction of the Commission, that public utility in respect of such other business shall be subject to inquiry, examination and inspection by the Commission in the same manner as the public utility business insofar as such inquiry, examination and inspection may be necessary to enforce any provision of this Act. The determination of the Commission that a necessity for any regulation of nonpublic business of a public utility exists shall be prima facie evidence of the fact in any action in a court of this State to enforce or set aside an order or ruling of the Commission.

Every public utility and affiliated interest thereof shall provide the Commission with access to books, records, accounts, documents and other data and information which the Commission finds necessary to effectively implement and effectuate the provisions of Section 7-204.

(Source: P.A. 84-617.)

(220 ILCS 5/7-206) (from Ch. 111 2/3, par. 7-206)

Sec. 7-206. Separate accounts for nonpublic business of public utility. The Commission may require every public utility engaged directly or indirectly in any other than a public utility business, as defined by law, to keep separately in like manner and form the accounts of all such other business, and the Commission may provide for the examination and inspection of the books, accounts, papers and records of such other business, in so far as may be necessary to enforce any provisions of this Act. The Commission shall have the power to inquire as to and prescribe the apportionment of capitalization, earnings, debts and expenses fairly and justly to be awarded to or borne by the ownership, operation, management or control of such public utility as distinguished from such other business. Provided, however, that an electric or gas public utility shall not be required to maintain the accounts of any non-public utility business in the same manner and form as the electric or gas public utility is required to keep the accounts of its public utility business unless expressly ordered by the Commission.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/7-207) (from Ch. 111 2/3, par. 7-207)

Sec. 7-207. Nonprofit affiliates.

(a) A public utility or telecommunications carrier may organize a not-for-profit corporation for the purpose of assisting low-income consumers in the acquisition of utility and telephone services. The not-for-profit corporation may be organized by a public utility, a telecommunications carrier, a combination of either or both, or in combination with any other person or organization upon application to and approval by the Commission.

(b) The Commission shall promulgate reasonable rules and regulations for the administration of this Section.

(Source: P.A. 87-449.)

(220 ILCS 5/7-208)

Sec. 7-208. HVAC affiliate marketing.

(a) "HVAC affiliate" means all affiliated interests of a gas utility that provide heating, ventilating, or air conditioning services to customers within the service territory of the affiliated gas utility.

(b) When an HVAC affiliate advertises or markets heating, ventilating, or air conditioning services to the public, it shall include a disclaimer that, if audible, is conspicuous and if printed is of sufficient size to be clearly legible, and that states:

(Insert name of affiliate) is an affiliate of (insert name of gas utility) and is not regulated by the Illinois Commerce Commission. Customers are not required to buy products or services from (insert name of affiliate) in order to receive the same quality of service from the gas utility.

(c) The requirements in subsection (b) apply to all forms of advertising and marketing, including, but not limited to, print, television, radio, internet, telephonic, bill inserts, and newsletters.

(Source: P.A. 92-852, eff. 8-26-02.)

(220 ILCS 5/7-209)

Sec. 7-209. Marketing limitation; gas utilities. If a gas utility has an HVAC affiliate, the prohibition contained in this Section applies to the employees of the gas utility. While a gas utility employee is responding to a service call related to services provided under tariffs on file with the Illinois Commerce Commission, the employee of the gas utility is prohibited from marketing the services of an HVAC affiliate; provided, however, the gas utility employee may refer the customer to the telephone directory in response to specific requests for referrals. If a customer's gas appliance or gas service has been disconnected due to an emergency situation that requires immediate attention, a gas utility employee may provide to that customer a list, including contact phone numbers, that includes HVAC affiliates and non-affiliated entities that provide heating, ventilating, or air conditioning services.

(Source: P.A. 92-852, eff. 8-26-02.)

(220 ILCS 5/7-210)

Sec. 7-210. Commission oversight of nonpublic, unregulated sales at retail of natural gas by public utilities.

(a) This Section shall apply to any gas utility that served more than 60,000 gas customers but less than 75,000 gas customers in this State on January 1, 2000 and that provides competitive electric power and energy to electric delivery service customers through a business division of its electric utility pursuant to Section 16-116. For the purposes of this Section, terms shall have the same meaning as defined in Section 7-108, Article XVI, and Article XIX.

(b) After the effective date of this amendatory Act of the 93rd General Assembly, unregulated sales of natural gas by a gas utility within or outside its service area shall be subject to the provisions of this Section. This Section shall not be interpreted to invalidate any contract for unregulated sales of natural gas executed by a gas utility prior to the effective date of this amendatory Act of the 93rd General Assembly, but unregulated sales of natural gas pursuant to such contract after the effective date of this amendatory Act of the 93rd General Assembly shall be subject to the provisions of this Section.

(c) A gas utility offering unregulated sales of natural gas to an end-use customer within or outside its service area shall be subject to Sections 7-102(g), 7-205, 7-206, and 9-230 with respect to such sales.

(d) Notwithstanding any language of Article XIX to the contrary, a gas utility offering unregulated sales of natural gas to a residential customer or a small commercial customer within or outside its service area shall be subject to Sections 19-110(e)(2), 19-110(e)(3), 19-110(e)(5), 19-115, and 19-120.

(e) A gas utility offering unregulated sales of natural gas to an end-use customer within or outside its service area shall not subsidize such sales through the utility's regulated business. Costs and revenues from the gas utility's unregulated sales of gas to an end-use customer within or outside its service area shall not be included in the calculation of the utility's regulated gas rates and charges.

(f) A gas utility offering unregulated sales of natural gas to an end-use customer within or outside its service area shall not discriminate in the provision of regulated gas service based upon the existence or terms of an unregulated sale of natural gas.

(g) The Commission shall require a gas utility to file reports regarding its unregulated sales of natural gas in the State. The reports shall be treated as confidential documents. To the extent the Commission determines it to be necessary and in the public interest, the Commission may order an audit of a gas utility regarding its unregulated sales of natural gas in the State.

(h) The Commission shall have the authority to require the gas utility to file its contracts for unregulated sales of natural gas in the State. The contracts shall be treated as confidential documents.

(i) Within 120 days after the effective date of this amendatory Act of the 93rd General Assembly, the Commission shall adopt provisions requiring functional separation between a gas utility's unregulated retail sales of natural gas in the State and its regulated retail gas services in the State. In establishing or considering the functional separations provisions, the Commission shall take into account the effects on the cost and reliability of service and the obligation of the gas utility under the Act. The Commission shall adopt separations provisions that are a cost effective means to ensure compliance with this Section. The provisions adopted by the Commission shall permit a gas utility to offer unregulated retail sales of natural gas in the State through the same business division of the utility that offers competitive electric power and energy to electric delivery service customers. Until provisions are adopted by the Commission, the gas utility shall comply with the functional separations rules for electric utilities adopted pursuant to Section 16-119A, to the extent determined applicable by the Commission through emergency rules established within 60 days of the passage of this Act.

(j) A gas utility shall not release or assign gas storage capacity procured for its regulated Illinois retail customers to its business division offering unregulated retail sales of natural gas or allow such storage capacity to be managed by that business division.

(k) Except as approved by the Commission, a gas utility shall not use gas commodity or interstate pipeline services for unregulated retail sales of natural gas in the State if such commodity or service was procured for its regulated Illinois retail customers.

(l) In addition to any other remedy provided in the Act, the Commission may order a gas utility to cease offering unregulated retail sales of natural gas in the State if it finds, after notice and hearing, that the gas utility willfully violated this Section.

(m) This Section shall not be applicable to unregulated sales of natural gas by an affiliate of a gas utility. Nothing herein shall be construed as impacting the applicability of other Sections of the Act to the unregulated sale of natural gas by an affiliate.

(Source: P.A. 93-1052, eff. 1-1-05.)

(220 ILCS 5/7-213)

Sec. 7-213. Limitations on the transfer of water systems.

(a) In the event of a sale, purchase, or any other transfer of ownership, including, without limitation, the acquisition by eminent domain, of a water system, as defined under Section 11-124-5 of the Illinois Municipal Code, operated by a privately held public water utility, the water utility's contract or agreements with the acquiring entity (or, in the case of an eminent domain action, the court order) must require that the acquiring entity hire a sufficient number of non-supervisory employees to operate and maintain the water system by initially making offers of employment to the non-supervisory workforce of the water system at no less than the wage rates, and substantially equivalent fringe benefits and terms and conditions of employment that are in effect at the time of transfer of ownership of the water system. The wage rates and substantially equivalent fringe benefits and terms and conditions of employment must continue for at least 30 months after the time of the transfer of ownership unless the parties mutually agree to different terms and conditions of employment within that 30-month period.

(b) The privately held public water utility shall offer a transition plan to those employees who are not offered jobs by the acquiring entity because that entity has a need for fewer workers. The transition plan shall mitigate employee job losses to the extent practical through such means as offers of voluntary severance, retraining, early retirement, out placement, or related benefits. Before any reduction in the workforce during a water system transaction, the privately held public water utility shall present to the employees, or their representatives, a transition plan outlining the means by which the utility intends to mitigate the impact of the workforce reduction of its employees.

(Source: P.A. 103-154, eff. 6-30-23.)

(220 ILCS 5/Art. VIII heading) ARTICLE VIII. SERVICE OBLIGATIONS AND CONDITIONS

(220 ILCS 5/8-101) (from Ch. 111 2/3, par. 8-101)

Sec. 8-101. Duties of public utilities; nondiscrimination. A public utility shall furnish, provide, and maintain such service instrumentalities, equipment, and facilities as shall promote the safety, health, comfort, and convenience of its patrons, employees, and public and as shall be in all respects adequate, efficient, just, and reasonable.

All rules and regulations made by a public utility affecting or pertaining to its charges or service to the public shall be just and reasonable.

A public utility shall, upon reasonable notice, furnish to all persons who may apply therefor and be reasonably entitled thereto, suitable facilities and service, without discrimination and without delay.

Nothing in this Section shall be construed to prevent a public utility from accepting payment electronically or by the use of a customer-preferred financially accredited credit or debit methodology.

(Source: P.A. 92-22, eff. 6-30-01.)

(220 ILCS 5/8-101.5)

Sec. 8-101.5. Use of credit information of prospective and existing customers. A public utility may not deny, cancel, or nonrenew utility service solely on the basis of credit information of prospective or existing customers. If a public utility denies, cancels, or does not renew service based on credit information, it must provide the affected party with an explanation for the public utility's action and an opportunity for the affected party to explain its credit information. This Section does not apply to a telecommunications carrier or any of its affiliates.

(Source: P.A. 96-560, eff. 8-18-09.)

(220 ILCS 5/8-102) (from Ch. 111 2/3, par. 8-102)

Sec. 8-102. Audit or investigation. The Commission is authorized to conduct or order a management audit or investigation of any public utility or part thereof. The audit or investigation may examine the reasonableness, prudence, or efficiency of any aspect of the utility's operations, costs, management, decisions or functions that may affect the adequacy, safety, efficiency or reliability of utility service or the reasonableness or prudence of the costs underlying rates or charges for utility service. The Commission may conduct or order a management audit or investigation only when it has reasonable grounds to believe that the audit or investigation is necessary to assure that the utility is providing adequate, efficient, reliable, safe, and least-cost service and charging only just and reasonable rates therefor, or that the audit or investigation is likely to be cost-beneficial in enhancing the quality of service or the reasonableness of rates therefor. The Commission shall, before initiating any such audit or investigation, issue an order describing the grounds for the audit or investigation and the appropriate scope and nature of the audit or investigation. The scope and nature of any such audit or investigation shall be reasonably related to the grounds relied upon by the Commission in its order.

Any audit or investigation authorized pursuant to this Section may be conducted by the Commission, or if the Commission is unable to adequately perform the audit or investigation, the Commission may arrange for it to be conducted by persons independent of the utility and selected by the Commission. The cost of an independent audit shall be borne initially by the utility, but shall be recovered as an expense through normal ratemaking procedures. Any audit or investigation shall be conducted in accordance with generally accepted auditing standards.

(Source: P.A. 90-655, eff. 7-30-98.)

(220 ILCS 5/8-103)

Sec. 8-103. Energy efficiency and demand-response measures.

(a) It is the policy of the State that electric utilities are required to use cost-effective energy efficiency and demand-response measures to reduce delivery load. Requiring investment in cost-effective energy efficiency and demand-response measures will reduce direct and indirect costs to consumers by decreasing environmental impacts and by avoiding or delaying the need for new generation, transmission, and distribution infrastructure. It serves the public interest to allow electric utilities to recover costs for reasonably and prudently incurred expenses for energy efficiency and demand-response measures. As used in this Section, "cost-effective" means that the measures satisfy the total resource cost test. The low-income measures described in subsection (f)(4) of this Section shall not be required to meet the total resource cost test. For purposes of this Section, the terms "energy-efficiency", "demand-response", "electric utility", and "total resource cost test" shall have the meanings set forth in the Illinois Power Agency Act. For purposes of this Section, the amount per kilowatthour means the total amount paid for electric service expressed on a per kilowatthour basis. For purposes of this Section, the total amount paid for electric service includes without limitation estimated amounts paid for supply, transmission, distribution, surcharges, and add-on-taxes.

(a-5) This Section applies to electric utilities serving 500,000 or less but more than 200,000 retail customers in this State. Through December 31, 2017, this Section also applies to electric utilities serving more than 500,000 retail customers in the State.

(b) Electric utilities shall implement cost-effective energy efficiency measures to meet the following incremental annual energy savings goals:

(1) 0.2% of energy delivered in the year commencing June 1, 2008;

(2) 0.4% of energy delivered in the year commencing June 1, 2009;

(3) 0.6% of energy delivered in the year commencing June 1, 2010;

(4) 0.8% of energy delivered in the year commencing June 1, 2011;

(5) 1% of energy delivered in the year commencing June 1, 2012;

(6) 1.4% of energy delivered in the year commencing June 1, 2013;

(7) 1.8% of energy delivered in the year commencing June 1, 2014; and

(8) 2% of energy delivered in the year commencing June 1, 2015 and each year thereafter.

Electric utilities may comply with this subsection (b) by meeting the annual incremental savings goal in the applicable year or by showing that the total cumulative annual savings within a 3-year planning period associated with measures implemented after May 31, 2014 was equal to the sum of each annual incremental savings requirement from May 31, 2014 through the end of the applicable year.

(c) Electric utilities shall implement cost-effective demand-response measures to reduce peak demand by 0.1% over the prior year for eligible retail customers, as defined in Section 16-111.5 of this Act, and for customers that elect hourly service from the utility pursuant to Section 16-107 of this Act, provided those customers have not been declared competitive. This requirement commences June 1, 2008 and continues for 10 years.

(d) Notwithstanding the requirements of subsections (b) and (c) of this Section, an electric utility shall reduce the amount of energy efficiency and demand-response measures implemented over a 3-year planning period by an amount necessary to limit the estimated average annual increase in the amounts paid by retail customers in connection with electric service due to the cost of those measures to:

(1) in 2008, no more than 0.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2007;

(2) in 2009, the greater of an additional 0.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2008 or 1% of the amount paid per kilowatthour by those customers during the year ending May 31, 2007;

(3) in 2010, the greater of an additional 0.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009 or 1.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2007;

(4) in 2011, the greater of an additional 0.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2010 or 2% of the amount paid per kilowatthour by those customers during the year ending May 31, 2007; and

(5) thereafter, the amount of energy efficiency and demand-response measures implemented for any single year shall be reduced by an amount necessary to limit the estimated average net increase due to the cost of these measures included in the amounts paid by eligible retail customers in connection with electric service to no more than the greater of 2.015% of the amount paid per kilowatthour by those customers during the year ending May 31, 2007 or the incremental amount per kilowatthour paid for these measures in 2011.

No later than June 30, 2011, the Commission shall review the limitation on the amount of energy efficiency and demand-response measures implemented pursuant to this Section and report to the General Assembly its findings as to whether that limitation unduly constrains the procurement of energy efficiency and demand-response measures.

(e) Electric utilities shall be responsible for overseeing the design, development, and filing of energy efficiency and demand-response plans with the Commission. Electric utilities shall implement 100% of the demand-response measures in the plans. Electric utilities shall implement 75% of the energy efficiency measures approved by the Commission, and may, as part of that implementation, outsource various aspects of program development and implementation. The remaining 25% of those energy efficiency measures approved by the Commission shall be implemented by the Department of Commerce and Economic Opportunity, and must be designed in conjunction with the utility and the filing process. The Department may outsource development and implementation of energy efficiency measures. A minimum of 10% of the entire portfolio of cost-effective energy efficiency measures shall be procured from units of local government, municipal corporations, school districts, public institutions of higher education, and community college districts. The Department shall coordinate the implementation of these measures.

The apportionment of the dollars to cover the costs to implement the Department's share of the portfolio of energy efficiency measures shall be made to the Department once the Department has executed rebate agreements, grants, or contracts for energy efficiency measures and provided supporting documentation for those rebate agreements, grants, and contracts to the utility. The Department is authorized to adopt any rules necessary and prescribe procedures in order to ensure compliance by applicants in carrying out the purposes of rebate agreements for energy efficiency measures implemented by the Department made under this Section.

The details of the measures implemented by the Department shall be submitted by the Department to the Commission in connection with the utility's filing regarding the energy efficiency and demand-response measures that the utility implements.

A utility providing approved energy efficiency and demand-response measures in the State shall be permitted to recover costs of those measures through an automatic adjustment clause tariff filed with and approved by the Commission. The tariff shall be established outside the context of a general rate case. Each year the Commission shall initiate a review to reconcile any amounts collected with the actual costs and to determine the required adjustment to the annual tariff factor to match annual expenditures.

Each utility shall include, in its recovery of costs, the costs estimated for both the utility's and the Department's implementation of energy efficiency and demand-response measures. Costs collected by the utility for measures implemented by the Department shall be submitted to the Department pursuant to Section 605-323 of the Civil Administrative Code of Illinois, shall be deposited into the Energy Efficiency Portfolio Standards Fund, and shall be used by the Department solely for the purpose of implementing these measures. A utility shall not be required to advance any moneys to the Department but only to forward such funds as it has collected. The Department shall report to the Commission on an annual basis regarding the costs actually incurred by the Department in the implementation of the measures. Any changes to the costs of energy efficiency measures as a result of plan modifications shall be appropriately reflected in amounts recovered by the utility and turned over to the Department.

The portfolio of measures, administered by both the utilities and the Department, shall, in combination, be designed to achieve the annual savings targets described in subsections (b) and (c) of this Section, as modified by subsection (d) of this Section.

The utility and the Department shall agree upon a reasonable portfolio of measures and determine the measurable corresponding percentage of the savings goals associated with measures implemented by the utility or Department.

No utility shall be assessed a penalty under subsection (f) of this Section for failure to make a timely filing if that failure is the result of a lack of agreement with the Department with respect to the allocation of responsibilities or related costs or target assignments. In that case, the Department and the utility shall file their respective plans with the Commission and the Commission shall determine an appropriate division of measures and programs that meets the requirements of this Section.

If the Department is unable to meet incremental annual performance goals for the portion of the portfolio implemented by the Department, then the utility and the Department shall jointly submit a modified filing to the Commission explaining the performance shortfall and recommending an appropriate course going forward, including any program modifications that may be appropriate in light of the evaluations conducted under item (7) of subsection (f) of this Section. In this case, the utility obligation to collect the Department's costs and turn over those funds to the Department under this subsection (e) shall continue only if the Commission approves the modifications to the plan proposed by the Department.

(f) No later than November 15, 2007, each electric utility shall file an energy efficiency and demand-response plan with the Commission to meet the energy efficiency and demand-response standards for 2008 through 2010. No later than October 1, 2010, each electric utility shall file an energy efficiency and demand-response plan with the Commission to meet the energy efficiency and demand-response standards for 2011 through 2013. Every 3 years thereafter, each electric utility shall file, no later than September 1, an energy efficiency and demand-response plan with the Commission. If a utility does not file such a plan by September 1 of an applicable year, it shall face a penalty of $100,000 per day until the plan is filed. Each utility's plan shall set forth the utility's proposals to meet the utility's portion of the energy efficiency standards identified in subsection (b) and the demand-response standards identified in subsection (c) of this Section as modified by subsections (d) and (e), taking into account the unique circumstances of the utility's service territory. The Commission shall seek public comment on the utility's plan and shall issue an order approving or disapproving each plan within 5 months after its submission. If the Commission disapproves a plan, the Commission shall, within 30 days, describe in detail the reasons for the disapproval and describe a path by which the utility may file a revised draft of the plan to address the Commission's concerns satisfactorily. If the utility does not refile with the Commission within 60 days, the utility shall be subject to penalties at a rate of $100,000 per day until the plan is filed. This process shall continue, and penalties shall accrue, until the utility has successfully filed a portfolio of energy efficiency and demand-response measures. Penalties shall be deposited into the Energy Efficiency Trust Fund. In submitting proposed energy efficiency and demand-response plans and funding levels to meet the savings goals adopted by this Act the utility shall:

(1) Demonstrate that its proposed energy efficiency and demand-response measures will achieve the requirements that are identified in subsections (b) and (c) of this Section, as modified by subsections (d) and (e).

(2) Present specific proposals to implement new building and appliance standards that have been placed into effect.

(3) Present estimates of the total amount paid for electric service expressed on a per kilowatthour basis associated with the proposed portfolio of measures designed to meet the requirements that are identified in subsections (b) and (c) of this Section, as modified by subsections (d) and (e).

(4) Coordinate with the Department to present a portfolio of energy efficiency measures proportionate to the share of total annual utility revenues in Illinois from households at or below 150% of the poverty level. The energy efficiency programs shall be targeted to households with incomes at or below 80% of area median income.

(5) Demonstrate that its overall portfolio of energy efficiency and demand-response measures, not including programs covered by item (4) of this subsection (f), are cost-effective using the total resource cost test and represent a diverse cross-section of opportunities for customers of all rate classes to participate in the programs.

(6) Include a proposed cost-recovery tariff mechanism to fund the proposed energy efficiency and demand-response measures and to ensure the recovery of the prudently and reasonably incurred costs of Commission-approved programs.

(7) Provide for an annual independent evaluation of the performance of the cost-effectiveness of the utility's portfolio of measures and the Department's portfolio of measures, as well as a full review of the 3-year results of the broader net program impacts and, to the extent practical, for adjustment of the measures on a going-forward basis as a result of the evaluations. The resources dedicated to evaluation shall not exceed 3% of portfolio resources in any given year.

(g) No more than 3% of energy efficiency and demand-response program revenue may be allocated for demonstration of breakthrough equipment and devices.

(h) This Section does not apply to an electric utility that on December 31, 2005 provided electric service to fewer than 100,000 customers in Illinois.

(i) If, after 2 years, an electric utility fails to meet the efficiency standard specified in subsection (b) of this Section, as modified by subsections (d) and (e), it shall make a contribution to the Low-Income Home Energy Assistance Program. The combined total liability for failure to meet the goal shall be $1,000,000, which shall be assessed as follows: a large electric utility shall pay $665,000, and a medium electric utility shall pay $335,000. If, after 3 years, an electric utility fails to meet the efficiency standard specified in subsection (b) of this Section, as modified by subsections (d) and (e), it shall make a contribution to the Low-Income Home Energy Assistance Program. The combined total liability for failure to meet the goal shall be $1,000,000, which shall be assessed as follows: a large electric utility shall pay $665,000, and a medium electric utility shall pay $335,000. In addition, the responsibility for implementing the energy efficiency measures of the utility making the payment shall be transferred to the Illinois Power Agency if, after 3 years, or in any subsequent 3-year period, the utility fails to meet the efficiency standard specified in subsection (b) of this Section, as modified by subsections (d) and (e). The Agency shall implement a competitive procurement program to procure resources necessary to meet the standards specified in this Section as modified by subsections (d) and (e), with costs for those resources to be recovered in the same manner as products purchased through the procurement plan as provided in Section 16-111.5. The Director shall implement this requirement in connection with the procurement plan as provided in Section 16-111.5.

For purposes of this Section, (i) a "large electric utility" is an electric utility that, on December 31, 2005, served more than 2,000,000 electric customers in Illinois; (ii) a "medium electric utility" is an electric utility that, on December 31, 2005, served 2,000,000 or fewer but more than 100,000 electric customers in Illinois; and (iii) Illinois electric utilities that are affiliated by virtue of a common parent company are considered a single electric utility.

(j) If, after 3 years, or any subsequent 3-year period, the Department fails to implement the Department's share of energy efficiency measures required by the standards in subsection (b), then the Illinois Power Agency may assume responsibility for and control of the Department's share of the required energy efficiency measures. The Agency shall implement a competitive procurement program to procure resources necessary to meet the standards specified in this Section, with the costs of these resources to be recovered in the same manner as provided for the Department in this Section.

(k) No electric utility shall be deemed to have failed to meet the energy efficiency standards to the extent any such failure is due to a failure of the Department or the Agency.

(l)(1) The energy efficiency and demand-response plans of electric utilities serving more than 500,000 retail customers in the State that were approved by the Commission on or before the effective date of this amendatory Act of the 99th General Assembly for the period June 1, 2014 through May 31, 2017 shall continue to be in force and effect through December 31, 2017 so that the energy efficiency programs set forth in those plans continue to be offered during the period June 1, 2017 through December 31, 2017. Each such utility is authorized to increase, on a pro rata basis, the energy savings goals and budgets approved in its plan to reflect the additional 7 months of the plan's operation, provided that such increase shall also incorporate reductions to goals and budgets to reflect the proportion of the utility's load attributable to customers who are exempt from this Section under subsection (m) of this Section.

(2) If an electric utility serving more than 500,000 retail customers in the State filed with the Commission, under subsection (f) of this Section, its proposed energy efficiency and demand-response plan for the period June 1, 2017 through May 31, 2020, and the Commission has not yet entered its final order approving such plan on or before the effective date of this amendatory Act of the 99th General Assembly, then the utility shall file a notice of withdrawal with the Commission, following such effective date, to withdraw the proposed energy efficiency and demand-response plan. Upon receipt of such notice, the Commission shall dismiss with prejudice any docket that had been initiated to investigate such plan, and the plan and the record related thereto shall not be the subject of any further hearing, investigation, or proceeding of any kind.

(3) For those electric utilities that serve more than 500,000 retail customers in the State, this amendatory Act of the 99th General Assembly preempts and supersedes any orders entered by the Commission that approved such utilities' energy efficiency and demand response plans for the period commencing June 1, 2017 and ending May 31, 2020. Any such orders shall be void, and the provisions of paragraph (1) of this subsection (l) shall apply.

(m) Notwithstanding anything to the contrary, after May 31, 2017, this Section does not apply to any retail customers of an electric utility that serves more than 3,000,000 retail customers in the State and whose total highest 30 minute demand was more than 10,000 kilowatts, or any retail customers of an electric utility that serves less than 3,000,000 retail customers but more than 500,000 retail customers in the State and whose total highest 15 minute demand was more than 10,000 kilowatts. For purposes of this subsection (m), "retail customer" has the meaning set forth in Section 16-102 of this Act. The criteria for determining whether this subsection (m) is applicable to a retail customer shall be based on the 12 consecutive billing periods prior to the start of the first year of each such multi-year plan.

(Source: P.A. 103-613, eff. 7-1-24.)

(220 ILCS 5/8-103A)

Sec. 8-103A. Energy efficiency analysis. Beginning in 2013, an electric utility subject to the requirements of Section 8-103 of this Act shall include in its energy efficiency and demand-response plan submitted pursuant to subsection (f) of Section 8-103 an analysis of additional cost-effective energy efficiency measures that could be implemented, by customer class, absent the limitations set forth in subsection (d) of Section 8-103. In seeking public comment on the electric utility's plan pursuant to subsection (f) of Section 8-103, the Commission shall include, beginning in 2013, the assessment of additional cost-effective energy efficiency measures submitted pursuant to this Section. For purposes of this Section, the term "energy efficiency" shall have the meaning set forth in Section 1-10 of the Illinois Power Agency Act, and the term "cost-effective" shall have the meaning set forth in subsection (a) of Section 8-103 of this Act.

(Source: P.A. 97-616, eff. 10-26-11.)

(220 ILCS 5/8-103B)

Sec. 8-103B. Energy efficiency and demand-response measures.

(a) It is the policy of the State that electric utilities are required to use cost-effective energy efficiency and demand-response measures to reduce delivery load. Requiring investment in cost-effective energy efficiency and demand-response measures will reduce direct and indirect costs to consumers by decreasing environmental impacts and by avoiding or delaying the need for new generation, transmission, and distribution infrastructure. It serves the public interest to allow electric utilities to recover costs for reasonably and prudently incurred expenditures for energy efficiency and demand-response measures. As used in this Section, "cost-effective" means that the measures satisfy the total resource cost test. The low-income measures described in subsection (c) of this Section shall not be required to meet the total resource cost test. For purposes of this Section, the terms "energy-efficiency", "demand-response", "electric utility", and "total resource cost test" have the meanings set forth in the Illinois Power Agency Act. "Black, indigenous, and people of color" and "BIPOC" means people who are members of the groups described in subparagraphs (a) through (e) of paragraph (A) of subsection (1) of Section 2 of the Business Enterprise for Minorities, Women, and Persons with Disabilities Act.

(a-5) This Section applies to electric utilities serving more than 500,000 retail customers in the State for those multi-year plans commencing after December 31, 2017.

(b) For purposes of this Section, electric utilities subject to this Section that serve more than 3,000,000 retail customers in the State shall be deemed to have achieved a cumulative persisting annual savings of 6.6% from energy efficiency measures and programs implemented during the period beginning January 1, 2012 and ending December 31, 2017, which percent is based on the deemed average weather normalized sales of electric power and energy during calendar years 2014, 2015, and 2016 of 88,000,000 MWhs. For the purposes of this subsection (b) and subsection (b-5), the 88,000,000 MWhs of deemed electric power and energy sales shall be reduced by the number of MWhs equal to the sum of the annual consumption of customers that have opted out of subsections (a) through (j) of this Section under paragraph (1) of subsection (l) of this Section, as averaged across the calendar years 2014, 2015, and 2016. After 2017, the deemed value of cumulative persisting annual savings from energy efficiency measures and programs implemented during the period beginning January 1, 2012 and ending December 31, 2017, shall be reduced each year, as follows, and the applicable value shall be applied to and count toward the utility's achievement of the cumulative persisting annual savings goals set forth in subsection (b-5):

(1) 5.8% deemed cumulative persisting annual savings for the year ending December 31, 2018;

(2) 5.2% deemed cumulative persisting annual savings for the year ending December 31, 2019;

(3) 4.5% deemed cumulative persisting annual savings for the year ending December 31, 2020;

(4) 4.0% deemed cumulative persisting annual savings for the year ending December 31, 2021;

(5) 3.5% deemed cumulative persisting annual savings for the year ending December 31, 2022;

(6) 3.1% deemed cumulative persisting annual savings for the year ending December 31, 2023;

(7) 2.8% deemed cumulative persisting annual savings for the year ending December 31, 2024;

(8) 2.5% deemed cumulative persisting annual savings for the year ending December 31, 2025;

(9) 2.3% deemed cumulative persisting annual savings for the year ending December 31, 2026;

(10) 2.1% deemed cumulative persisting annual savings for the year ending December 31, 2027;

(11) 1.8% deemed cumulative persisting annual savings for the year ending December 31, 2028;

(12) 1.7% deemed cumulative persisting annual savings for the year ending December 31, 2029;

(13) 1.5% deemed cumulative persisting annual savings for the year ending December 31, 2030;

(14) 1.3% deemed cumulative persisting annual savings for the year ending December 31, 2031;

(15) 1.1% deemed cumulative persisting annual savings for the year ending December 31, 2032;

(16) 0.9% deemed cumulative persisting annual savings for the year ending December 31, 2033;

(17) 0.7% deemed cumulative persisting annual savings for the year ending December 31, 2034;

(18) 0.5% deemed cumulative persisting annual savings for the year ending December 31, 2035;

(19) 0.4% deemed cumulative persisting annual savings for the year ending December 31, 2036;

(20) 0.3% deemed cumulative persisting annual savings for the year ending December 31, 2037;

(21) 0.2% deemed cumulative persisting annual savings for the year ending December 31, 2038;

(22) 0.1% deemed cumulative persisting annual savings for the year ending December 31, 2039; and

(23) 0.0% deemed cumulative persisting annual savings for the year ending December 31, 2040 and all subsequent years.

For purposes of this Section, "cumulative persisting annual savings" means the total electric energy savings in a given year from measures installed in that year or in previous years, but no earlier than January 1, 2012, that are still operational and providing savings in that year because the measures have not yet reached the end of their useful lives.

(b-5) Beginning in 2018, electric utilities subject to this Section that serve more than 3,000,000 retail customers in the State shall achieve the following cumulative persisting annual savings goals, as modified by subsection (f) of this Section and as compared to the deemed baseline of 88,000,000 MWhs of electric power and energy sales set forth in subsection (b), as reduced by the number of MWhs equal to the sum of the annual consumption of customers that have opted out of subsections (a) through (j) of this Section under paragraph (1) of subsection (l) of this Section as averaged across the calendar years 2014, 2015, and 2016, through the implementation of energy efficiency measures during the applicable year and in prior years, but no earlier than January 1, 2012:

(1) 7.8% cumulative persisting annual savings for the year ending December 31, 2018;

(2) 9.1% cumulative persisting annual savings for the year ending December 31, 2019;

(3) 10.4% cumulative persisting annual savings for the year ending December 31, 2020;

(4) 11.8% cumulative persisting annual savings for the year ending December 31, 2021;

(5) 13.1% cumulative persisting annual savings for the year ending December 31, 2022;

(6) 14.4% cumulative persisting annual savings for the year ending December 31, 2023;

(7) 15.7% cumulative persisting annual savings for the year ending December 31, 2024;

(8) 17% cumulative persisting annual savings for the year ending December 31, 2025;

(9) 17.9% cumulative persisting annual savings for the year ending December 31, 2026;

(10) 18.8% cumulative persisting annual savings for the year ending December 31, 2027;

(11) 19.7% cumulative persisting annual savings for the year ending December 31, 2028;

(12) 20.6% cumulative persisting annual savings for the year ending December 31, 2029; and

(13) 21.5% cumulative persisting annual savings for the year ending December 31, 2030.

No later than December 31, 2021, the Illinois Commerce Commission shall establish additional cumulative persisting annual savings goals for the years 2031 through 2035. No later than December 31, 2024, the Illinois Commerce Commission shall establish additional cumulative persisting annual savings goals for the years 2036 through 2040. The Commission shall also establish additional cumulative persisting annual savings goals every 5 years thereafter to ensure that utilities always have goals that extend at least 11 years into the future. The cumulative persisting annual savings goals beyond the year 2030 shall increase by 0.9 percentage points per year, absent a Commission decision to initiate a proceeding to consider establishing goals that increase by more or less than that amount. Such a proceeding must be conducted in accordance with the procedures described in subsection (f) of this Section. If such a proceeding is initiated, the cumulative persisting annual savings goals established by the Commission through that proceeding shall reflect the Commission's best estimate of the maximum amount of additional savings that are forecast to be cost-effectively achievable unless such best estimates would result in goals that represent less than 0.5 percentage point annual increases in total cumulative persisting annual savings. The Commission may only establish goals that represent less than 0.5 percentage point annual increases in cumulative persisting annual savings if it can demonstrate, based on clear and convincing evidence and through independent analysis, that 0.5 percentage point increases are not cost-effectively achievable. The Commission shall inform its decision based on an energy efficiency potential study that conforms to the requirements of this Section.

(b-10) For purposes of this Section, electric utilities subject to this Section that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State shall be deemed to have achieved a cumulative persisting annual savings of 6.6% from energy efficiency measures and programs implemented during the period beginning January 1, 2012 and ending December 31, 2017, which is based on the deemed average weather normalized sales of electric power and energy during calendar years 2014, 2015, and 2016 of 36,900,000 MWhs. For the purposes of this subsection (b-10) and subsection (b-15), the 36,900,000 MWhs of deemed electric power and energy sales shall be reduced by the number of MWhs equal to the sum of the annual consumption of customers that have opted out of subsections (a) through (j) of this Section under paragraph (1) of subsection (l) of this Section, as averaged across the calendar years 2014, 2015, and 2016. After 2017, the deemed value of cumulative persisting annual savings from energy efficiency measures and programs implemented during the period beginning January 1, 2012 and ending December 31, 2017, shall be reduced each year, as follows, and the applicable value shall be applied to and count toward the utility's achievement of the cumulative persisting annual savings goals set forth in subsection (b-15):

(1) 5.8% deemed cumulative persisting annual savings for the year ending December 31, 2018;

(2) 5.2% deemed cumulative persisting annual savings for the year ending December 31, 2019;

(3) 4.5% deemed cumulative persisting annual savings for the year ending December 31, 2020;

(4) 4.0% deemed cumulative persisting annual savings for the year ending December 31, 2021;

(5) 3.5% deemed cumulative persisting annual savings for the year ending December 31, 2022;

(6) 3.1% deemed cumulative persisting annual savings for the year ending December 31, 2023;

(7) 2.8% deemed cumulative persisting annual savings for the year ending December 31, 2024;

(8) 2.5% deemed cumulative persisting annual savings for the year ending December 31, 2025;

(9) 2.3% deemed cumulative persisting annual savings for the year ending December 31, 2026;

(10) 2.1% deemed cumulative persisting annual savings for the year ending December 31, 2027;

(11) 1.8% deemed cumulative persisting annual savings for the year ending December 31, 2028;

(12) 1.7% deemed cumulative persisting annual savings for the year ending December 31, 2029;

(13) 1.5% deemed cumulative persisting annual savings for the year ending December 31, 2030;

(14) 1.3% deemed cumulative persisting annual savings for the year ending December 31, 2031;

(15) 1.1% deemed cumulative persisting annual savings for the year ending December 31, 2032;

(16) 0.9% deemed cumulative persisting annual savings for the year ending December 31, 2033;

(17) 0.7% deemed cumulative persisting annual savings for the year ending December 31, 2034;

(18) 0.5% deemed cumulative persisting annual savings for the year ending December 31, 2035;

(19) 0.4% deemed cumulative persisting annual savings for the year ending December 31, 2036;

(20) 0.3% deemed cumulative persisting annual savings for the year ending December 31, 2037;

(21) 0.2% deemed cumulative persisting annual savings for the year ending December 31, 2038;

(22) 0.1% deemed cumulative persisting annual savings for the year ending December 31, 2039; and

(23) 0.0% deemed cumulative persisting annual savings for the year ending December 31, 2040 and all subsequent years.

(b-15) Beginning in 2018, electric utilities subject to this Section that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State shall achieve the following cumulative persisting annual savings goals, as modified by subsection (b-20) and subsection (f) of this Section and as compared to the deemed baseline as reduced by the number of MWhs equal to the sum of the annual consumption of customers that have opted out of subsections (a) through (j) of this Section under paragraph (1) of subsection (l) of this Section as averaged across the calendar years 2014, 2015, and 2016, through the implementation of energy efficiency measures during the applicable year and in prior years, but no earlier than January 1, 2012:

(1) 7.4% cumulative persisting annual savings for the year ending December 31, 2018;

(2) 8.2% cumulative persisting annual savings for the year ending December 31, 2019;

(3) 9.0% cumulative persisting annual savings for the year ending December 31, 2020;

(4) 9.8% cumulative persisting annual savings for the year ending December 31, 2021;

(5) 10.6% cumulative persisting annual savings for the year ending December 31, 2022;

(6) 11.4% cumulative persisting annual savings for the year ending December 31, 2023;

(7) 12.2% cumulative persisting annual savings for the year ending December 31, 2024;

(8) 13% cumulative persisting annual savings for the year ending December 31, 2025;

(9) 13.6% cumulative persisting annual savings for the year ending December 31, 2026;

(10) 14.2% cumulative persisting annual savings for the year ending December 31, 2027;

(11) 14.8% cumulative persisting annual savings for the year ending December 31, 2028;

(12) 15.4% cumulative persisting annual savings for the year ending December 31, 2029; and

(13) 16% cumulative persisting annual savings for the year ending December 31, 2030.

No later than December 31, 2021, the Illinois Commerce Commission shall establish additional cumulative persisting annual savings goals for the years 2031 through 2035. No later than December 31, 2024, the Illinois Commerce Commission shall establish additional cumulative persisting annual savings goals for the years 2036 through 2040. The Commission shall also establish additional cumulative persisting annual savings goals every 5 years thereafter to ensure that utilities always have goals that extend at least 11 years into the future. The cumulative persisting annual savings goals beyond the year 2030 shall increase by 0.6 percentage points per year, absent a Commission decision to initiate a proceeding to consider establishing goals that increase by more or less than that amount. Such a proceeding must be conducted in accordance with the procedures described in subsection (f) of this Section. If such a proceeding is initiated, the cumulative persisting annual savings goals established by the Commission through that proceeding shall reflect the Commission's best estimate of the maximum amount of additional savings that are forecast to be cost-effectively achievable unless such best estimates would result in goals that represent less than 0.4 percentage point annual increases in total cumulative persisting annual savings. The Commission may only establish goals that represent less than 0.4 percentage point annual increases in cumulative persisting annual savings if it can demonstrate, based on clear and convincing evidence and through independent analysis, that 0.4 percentage point increases are not cost-effectively achievable. The Commission shall inform its decision based on an energy efficiency potential study that conforms to the requirements of this Section.

(b-20) Each electric utility subject to this Section may include cost-effective voltage optimization measures in its plans submitted under subsections (f) and (g) of this Section, and the costs incurred by a utility to implement the measures under a Commission-approved plan shall be recovered under the provisions of Article IX or Section 16-108.5 of this Act. For purposes of this Section, the measure life of voltage optimization measures shall be 15 years. The measure life period is independent of the depreciation rate of the voltage optimization assets deployed. Utilities may claim savings from voltage optimization on circuits for more than 15 years if they can demonstrate that they have made additional investments necessary to enable voltage optimization savings to continue beyond 15 years. Such demonstrations must be subject to the review of independent evaluation.

Within 270 days after June 1, 2017 (the effective date of Public Act 99-906), an electric utility that serves less than 3,000,000 retail customers but more than 500,000 retail customers in the State shall file a plan with the Commission that identifies the cost-effective voltage optimization investment the electric utility plans to undertake through December 31, 2024. The Commission, after notice and hearing, shall approve or approve with modification the plan within 120 days after the plan's filing and, in the order approving or approving with modification the plan, the Commission shall adjust the applicable cumulative persisting annual savings goals set forth in subsection (b-15) to reflect any amount of cost-effective energy savings approved by the Commission that is greater than or less than the following cumulative persisting annual savings values attributable to voltage optimization for the applicable year:

(1) 0.0% of cumulative persisting annual savings for the year ending December 31, 2018;

(2) 0.17% of cumulative persisting annual savings for the year ending December 31, 2019;

(3) 0.17% of cumulative persisting annual savings for the year ending December 31, 2020;

(4) 0.33% of cumulative persisting annual savings for the year ending December 31, 2021;

(5) 0.5% of cumulative persisting annual savings for the year ending December 31, 2022;

(6) 0.67% of cumulative persisting annual savings for the year ending December 31, 2023;

(7) 0.83% of cumulative persisting annual savings for the year ending December 31, 2024; and

(8) 1.0% of cumulative persisting annual savings for the year ending December 31, 2025 and all subsequent years.

(b-25) In the event an electric utility jointly offers an energy efficiency measure or program with a gas utility under plans approved under this Section and Section 8-104 of this Act, the electric utility may continue offering the program, including the gas energy efficiency measures, in the event the gas utility discontinues funding the program. In that event, the energy savings value associated with such other fuels shall be converted to electric energy savings on an equivalent Btu basis for the premises. However, the electric utility shall prioritize programs for low-income residential customers to the extent practicable. An electric utility may recover the costs of offering the gas energy efficiency measures under this subsection (b-25).

For those energy efficiency measures or programs that save both electricity and other fuels but are not jointly offered with a gas utility under plans approved under this Section and Section 8-104 or not offered with an affiliated gas utility under paragraph (6) of subsection (f) of Section 8-104 of this Act, the electric utility may count savings of fuels other than electricity toward the achievement of its annual savings goal, and the energy savings value associated with such other fuels shall be converted to electric energy savings on an equivalent Btu basis at the premises.

In no event shall more than 10% of each year's applicable annual total savings requirement as defined in paragraph (7.5) of subsection (g) of this Section be met through savings of fuels other than electricity.

(b-27) Beginning in 2022, an electric utility may offer and promote measures that electrify space heating, water heating, cooling, drying, cooking, industrial processes, and other building and industrial end uses that would otherwise be served by combustion of fossil fuel at the premises, provided that the electrification measures reduce total energy consumption at the premises. The electric utility may count the reduction in energy consumption at the premises toward achievement of its annual savings goals. The reduction in energy consumption at the premises shall be calculated as the difference between: (A) the reduction in Btu consumption of fossil fuels as a result of electrification, converted to kilowatt-hour equivalents by dividing by 3,412 Btus per kilowatt hour; and (B) the increase in kilowatt hours of electricity consumption resulting from the displacement of fossil fuel consumption as a result of electrification. An electric utility may recover the costs of offering and promoting electrification measures under this subsection (b-27).

In no event shall electrification savings counted toward each year's applicable annual total savings requirement, as defined in paragraph (7.5) of subsection (g) of this Section, be greater than:

(1) 5% per year for each year from 2022 through 2025;

(2) 10% per year for each year from 2026 through 2029; and

(3) 15% per year for 2030 and all subsequent years.

In addition, a minimum of 25% of all electrification savings counted toward a utility's applicable annual total savings requirement must be from electrification of end uses in low-income housing. The limitations on electrification savings that may be counted toward a utility's annual savings goals are separate from and in addition to the subsection (b-25) limitations governing the counting of the other fuel savings resulting from efficiency measures and programs.

As part of the annual informational filing to the Commission that is required under paragraph (9) of subsection (g) of this Section, each utility shall identify the specific electrification measures offered under this subsection (b-27); the quantity of each electrification measure that was installed by its customers; the average total cost, average utility cost, average reduction in fossil fuel consumption, and average increase in electricity consumption associated with each electrification measure; the portion of installations of each electrification measure that were in low-income single-family housing, low-income multifamily housing, non-low-income single-family housing, non-low-income multifamily housing, commercial buildings, and industrial facilities; and the quantity of savings associated with each measure category in each customer category that are being counted toward the utility's applicable annual total savings requirement. Prior to installing an electrification measure, the utility shall provide a customer with an estimate of the impact of the new measure on the customer's average monthly electric bill and total annual energy expenses.

(c) Electric utilities shall be responsible for overseeing the design, development, and filing of energy efficiency plans with the Commission and may, as part of that implementation, outsource various aspects of program development and implementation. A minimum of 10%, for electric utilities that serve more than 3,000,000 retail customers in the State, and a minimum of 7%, for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State, of the utility's entire portfolio funding level for a given year shall be used to procure cost-effective energy efficiency measures from units of local government, municipal corporations, school districts, public housing, public institutions of higher education, and community college districts, provided that a minimum percentage of available funds shall be used to procure energy efficiency from public housing, which percentage shall be equal to public housing's share of public building energy consumption.

The utilities shall also implement energy efficiency measures targeted at low-income households, which, for purposes of this Section, shall be defined as households at or below 80% of area median income, and expenditures to implement the measures shall be no less than $40,000,000 per year for electric utilities that serve more than 3,000,000 retail customers in the State and no less than $13,000,000 per year for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State. The ratio of spending on efficiency programs targeted at low-income multifamily buildings to spending on efficiency programs targeted at low-income single-family buildings shall be designed to achieve levels of savings from each building type that are approximately proportional to the magnitude of cost-effective lifetime savings potential in each building type. Investment in low-income whole-building weatherization programs shall constitute a minimum of 80% of a utility's total budget specifically dedicated to serving low-income customers.

The utilities shall work to bundle low-income energy efficiency offerings with other programs that serve low-income households to maximize the benefits going to these households. The utilities shall market and implement low-income energy efficiency programs in coordination with low-income assistance programs, the Illinois Solar for All Program, and weatherization whenever practicable. The program implementer shall walk the customer through the enrollment process for any programs for which the customer is eligible. The utilities shall also pilot targeting customers with high arrearages, high energy intensity (ratio of energy usage divided by home or unit square footage), or energy assistance programs with energy efficiency offerings, and then track reduction in arrearages as a result of the targeting. This targeting and bundling of low-income energy programs shall be offered to both low-income single-family and multifamily customers (owners and residents).

The utilities shall invest in health and safety measures appropriate and necessary for comprehensively weatherizing a home or multifamily building, and shall implement a health and safety fund of at least 15% of the total income-qualified weatherization budget that shall be used for the purpose of making grants for technical assistance, construction, reconstruction, improvement, or repair of buildings to facilitate their participation in the energy efficiency programs targeted at low-income single-family and multifamily households. These funds may also be used for the purpose of making grants for technical assistance, construction, reconstruction, improvement, or repair of the following buildings to facilitate their participation in the energy efficiency programs created by this Section: (1) buildings that are owned or operated by registered 501(c)(3) public charities; and (2) day care centers, day care homes, or group day care homes, as defined under 89 Ill. Adm. Code Part 406, 407, or 408, respectively.

Each electric utility shall assess opportunities to implement cost-effective energy efficiency measures and programs through a public housing authority or authorities located in its service territory. If such opportunities are identified, the utility shall propose such measures and programs to address the opportunities. Expenditures to address such opportunities shall be credited toward the minimum procurement and expenditure requirements set forth in this subsection (c).

Implementation of energy efficiency measures and programs targeted at low-income households should be contracted, when it is practicable, to independent third parties that have demonstrated capabilities to serve such households, with a preference for not-for-profit entities and government agencies that have existing relationships with or experience serving low-income communities in the State.

Each electric utility shall develop and implement reporting procedures that address and assist in determining the amount of energy savings that can be applied to the low-income procurement and expenditure requirements set forth in this subsection (c). Each electric utility shall also track the types and quantities or volumes of insulation and air sealing materials, and their associated energy saving benefits, installed in energy efficiency programs targeted at low-income single-family and multifamily households.

The electric utilities shall participate in a low-income energy efficiency accountability committee ("the committee"), which will directly inform the design, implementation, and evaluation of the low-income and public-housing energy efficiency programs. The committee shall be comprised of the electric utilities subject to the requirements of this Section, the gas utilities subject to the requirements of Section 8-104 of this Act, the utilities' low-income energy efficiency implementation contractors, nonprofit organizations, community action agencies, advocacy groups, State and local governmental agencies, public-housing organizations, and representatives of community-based organizations, especially those living in or working with environmental justice communities and BIPOC communities. The committee shall be composed of 2 geographically differentiated subcommittees: one for stakeholders in northern Illinois and one for stakeholders in central and southern Illinois. The subcommittees shall meet together at least twice per year.

There shall be one statewide leadership committee led by and composed of community-based organizations that are representative of BIPOC and environmental justice communities and that includes equitable representation from BIPOC communities. The leadership committee shall be composed of an equal number of representatives from the 2 subcommittees. The subcommittees shall address specific programs and issues, with the leadership committee convening targeted workgroups as needed. The leadership committee may elect to work with an independent facilitator to solicit and organize feedback, recommendations and meeting participation from a wide variety of community-based stakeholders. If a facilitator is used, they shall be fair and responsive to the needs of all stakeholders involved in the committee.

All committee meetings must be accessible, with rotating locations if meetings are held in-person, virtual participation options, and materials and agendas circulated in advance.

There shall also be opportunities for direct input by committee members outside of committee meetings, such as via individual meetings, surveys, emails and calls, to ensure robust participation by stakeholders with limited capacity and ability to attend committee meetings. Committee meetings shall emphasize opportunities to bundle and coordinate delivery of low-income energy efficiency with other programs that serve low-income communities, such as the Illinois Solar for All Program and bill payment assistance programs. Meetings shall include educational opportunities for stakeholders to learn more about these additional offerings, and the committee shall assist in figuring out the best methods for coordinated delivery and implementation of offerings when serving low-income communities. The committee shall directly and equitably influence and inform utility low-income and public-housing energy efficiency programs and priorities. Participating utilities shall implement recommendations from the committee whenever possible.

Participating utilities shall track and report how input from the committee has led to new approaches and changes in their energy efficiency portfolios. This reporting shall occur at committee meetings and in quarterly energy efficiency reports to the Stakeholder Advisory Group and Illinois Commerce Commission, and other relevant reporting mechanisms. Participating utilities shall also report on relevant equity data and metrics requested by the committee, such as energy burden data, geographic, racial, and other relevant demographic data on where programs are being delivered and what populations programs are serving.

The Illinois Commerce Commission shall oversee and have relevant staff participate in the committee. The committee shall have a budget of 0.25% of each utility's entire efficiency portfolio funding for a given year. The budget shall be overseen by the Commission. The budget shall be used to provide grants for community-based organizations serving on the leadership committee, stipends for community-based organizations participating in the committee, grants for community-based organizations to do energy efficiency outreach and education, and relevant meeting needs as determined by the leadership committee. The education and outreach shall include, but is not limited to, basic energy efficiency education, information about low-income energy efficiency programs, and information on the committee's purpose, structure, and activities.

(d) Notwithstanding any other provision of law to the contrary, a utility providing approved energy efficiency measures and, if applicable, demand-response measures in the State shall be permitted to recover all reasonable and prudently incurred costs of those measures from all retail customers, except as provided in subsection (l) of this Section, as follows, provided that nothing in this subsection (d) permits the double recovery of such costs from customers:

(1) The utility may recover its costs through an automatic adjustment clause tariff filed with and approved by the Commission. The tariff shall be established outside the context of a general rate case. Each year the Commission shall initiate a review to reconcile any amounts collected with the actual costs and to determine the required adjustment to the annual tariff factor to match annual expenditures. To enable the financing of the incremental capital expenditures, including regulatory assets, for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State, the utility's actual year-end capital structure that includes a common equity ratio, excluding goodwill, of up to and including 50% of the total capital structure shall be deemed reasonable and used to set rates.

(2) A utility may recover its costs through an energy efficiency formula rate approved by the Commission under a filing under subsections (f) and (g) of this Section, which shall specify the cost components that form the basis of the rate charged to customers with sufficient specificity to operate in a standardized manner and be updated annually with transparent information that reflects the utility's actual costs to be recovered during the applicable rate year, which is the period beginning with the first billing day of January and extending through the last billing day of the following December. The energy efficiency formula rate shall be implemented through a tariff filed with the Commission under subsections (f) and (g) of this Section that is consistent with the provisions of this paragraph (2) and that shall be applicable to all delivery services customers. The Commission shall conduct an investigation of the tariff in a manner consistent with the provisions of this paragraph (2), subsections (f) and (g) of this Section, and the provisions of Article IX of this Act to the extent they do not conflict with this paragraph (2). The energy efficiency formula rate approved by the Commission shall remain in effect at the discretion of the utility and shall do the following:

(A) Provide for the recovery of the utility's actual costs incurred under this Section that are prudently incurred and reasonable in amount consistent with Commission practice and law. The sole fact that a cost differs from that incurred in a prior calendar year or that an investment is different from that made in a prior calendar year shall not imply the imprudence or unreasonableness of that cost or investment.

(B) Reflect the utility's actual year-end capital structure for the applicable calendar year, excluding goodwill, subject to a determination of prudence and reasonableness consistent with Commission practice and law. To enable the financing of the incremental capital expenditures, including regulatory assets, for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State, a participating electric utility's actual year-end capital structure that includes a common equity ratio, excluding goodwill, of up to and including 50% of the total capital structure shall be deemed reasonable and used to set rates.

(C) Include a cost of equity, which shall be calculated as the sum of the following:

(i) the average for the applicable calendar year of the monthly average yields of 30-year U.S. Treasury bonds published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication; and

(ii) 580 basis points.

At such time as the Board of Governors of the Federal Reserve System ceases to include the monthly average yields of 30-year U.S. Treasury bonds in its weekly H.15 Statistical Release or successor publication, the monthly average yields of the U.S. Treasury bonds then having the longest duration published by the Board of Governors in its weekly H.15 Statistical Release or successor publication shall instead be used for purposes of this paragraph (2).

(D) Permit and set forth protocols, subject to a determination of prudence and reasonableness consistent with Commission practice and law, for the following:

(i) recovery of incentive compensation expense that is based on the achievement of operational metrics, including metrics related to budget controls, outage duration and frequency, safety, customer service, efficiency and productivity, and environmental compliance; however, this protocol shall not apply if such expense related to costs incurred under this Section is recovered under Article IX or Section 16-108.5 of this Act; incentive compensation expense that is based on net income or an affiliate's earnings per share shall not be recoverable under the energy efficiency formula rate;

(ii) recovery of pension and other post-employment benefits expense, provided that such costs are supported by an actuarial study; however, this protocol shall not apply if such expense related to costs incurred under this Section is recovered under Article IX or Section 16-108.5 of this Act;

(iii) recovery of existing regulatory assets over the periods previously authorized by the Commission;

(iv) as described in subsection (e), amortization of costs incurred under this Section; and

(v) projected, weather normalized billing determinants for the applicable rate year.

(E) Provide for an annual reconciliation, as described in paragraph (3) of this subsection (d), less any deferred taxes related to the reconciliation, with interest at an annual rate of return equal to the utility's weighted average cost of capital, including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return, of the energy efficiency revenue requirement reflected in rates for each calendar year, beginning with the calendar year in which the utility files its energy efficiency formula rate tariff under this paragraph (2), with what the revenue requirement would have been had the actual cost information for the applicable calendar year been available at the filing date.

The utility shall file, together with its tariff, the projected costs to be incurred by the utility during the rate year under the utility's multi-year plan approved under subsections (f) and (g) of this Section, including, but not limited to, the projected capital investment costs and projected regulatory asset balances with correspondingly updated depreciation and amortization reserves and expense, that shall populate the energy efficiency formula rate and set the initial rates under the formula.

The Commission shall review the proposed tariff in conjunction with its review of a proposed multi-year plan, as specified in paragraph (5) of subsection (g) of this Section. The review shall be based on the same evidentiary standards, including, but not limited to, those concerning the prudence and reasonableness of the costs incurred by the utility, the Commission applies in a hearing to review a filing for a general increase in rates under Article IX of this Act. The initial rates shall take effect beginning with the January monthly billing period following the Commission's approval.

The tariff's rate design and cost allocation across customer classes shall be consistent with the utility's automatic adjustment clause tariff in effect on June 1, 2017 (the effective date of Public Act 99-906); however, the Commission may revise the tariff's rate design and cost allocation in subsequent proceedings under paragraph (3) of this subsection (d).

If the energy efficiency formula rate is terminated, the then current rates shall remain in effect until such time as the energy efficiency costs are incorporated into new rates that are set under this subsection (d) or Article IX of this Act, subject to retroactive rate adjustment, with interest, to reconcile rates charged with actual costs.

(3) The provisions of this paragraph (3) shall only apply to an electric utility that has elected to file an energy efficiency formula rate under paragraph (2) of this subsection (d). Subsequent to the Commission's issuance of an order approving the utility's energy efficiency formula rate structure and protocols, and initial rates under paragraph (2) of this subsection (d), the utility shall file, on or before June 1 of each year, with the Chief Clerk of the Commission its updated cost inputs to the energy efficiency formula rate for the applicable rate year and the corresponding new charges, as well as the information described in paragraph (9) of subsection (g) of this Section. Each such filing shall conform to the following requirements and include the following information:

(A) The inputs to the energy efficiency formula rate for the applicable rate year shall be based on the projected costs to be incurred by the utility during the rate year under the utility's multi-year plan approved under subsections (f) and (g) of this Section, including, but not limited to, projected capital investment costs and projected regulatory asset balances with correspondingly updated depreciation and amortization reserves and expense. The filing shall also include a reconciliation of the energy efficiency revenue requirement that was in effect for the prior rate year (as set by the cost inputs for the prior rate year) with the actual revenue requirement for the prior rate year (determined using a year-end rate base) that uses amounts reflected in the applicable FERC Form 1 that reports the actual costs for the prior rate year. Any over-collection or under-collection indicated by such reconciliation shall be reflected as a credit against, or recovered as an additional charge to, respectively, with interest calculated at a rate equal to the utility's weighted average cost of capital approved by the Commission for the prior rate year, the charges for the applicable rate year. Such over-collection or under-collection shall be adjusted to remove any deferred taxes related to the reconciliation, for purposes of calculating interest at an annual rate of return equal to the utility's weighted average cost of capital approved by the Commission for the prior rate year, including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return. Each reconciliation shall be certified by the participating utility in the same manner that FERC Form 1 is certified. The filing shall also include the charge or credit, if any, resulting from the calculation required by subparagraph (E) of paragraph (2) of this subsection (d).

Notwithstanding any other provision of law to the contrary, the intent of the reconciliation is to ultimately reconcile both the revenue requirement reflected in rates for each calendar year, beginning with the calendar year in which the utility files its energy efficiency formula rate tariff under paragraph (2) of this subsection (d), with what the revenue requirement determined using a year-end rate base for the applicable calendar year would have been had the actual cost information for the applicable calendar year been available at the filing date.

For purposes of this Section, "FERC Form 1" means the Annual Report of Major Electric Utilities, Licensees and Others that electric utilities are required to file with the Federal Energy Regulatory Commission under the Federal Power Act, Sections 3, 4(a), 304 and 209, modified as necessary to be consistent with 83 Ill. Adm. Code Part 415 as of May 1, 2011. Nothing in this Section is intended to allow costs that are not otherwise recoverable to be recoverable by virtue of inclusion in FERC Form 1.

(B) The new charges shall take effect beginning on the first billing day of the following January billing period and remain in effect through the last billing day of the next December billing period regardless of whether the Commission enters upon a hearing under this paragraph (3).

(C) The filing shall include relevant and necessary data and documentation for the applicable rate year. Normalization adjustments shall not be required.

Within 45 days after the utility files its annual update of cost inputs to the energy efficiency formula rate, the Commission shall with reasonable notice, initiate a proceeding concerning whether the projected costs to be incurred by the utility and recovered during the applicable rate year, and that are reflected in the inputs to the energy efficiency formula rate, are consistent with the utility's approved multi-year plan under subsections (f) and (g) of this Section and whether the costs incurred by the utility during the prior rate year were prudent and reasonable. The Commission shall also have the authority to investigate the information and data described in paragraph (9) of subsection (g) of this Section, including the proposed adjustment to the utility's return on equity component of its weighted average cost of capital. During the course of the proceeding, each objection shall be stated with particularity and evidence provided in support thereof, after which the utility shall have the opportunity to rebut the evidence. Discovery shall be allowed consistent with the Commission's Rules of Practice, which Rules of Practice shall be enforced by the Commission or the assigned administrative law judge. The Commission shall apply the same evidentiary standards, including, but not limited to, those concerning the prudence and reasonableness of the costs incurred by the utility, during the proceeding as it would apply in a proceeding to review a filing for a general increase in rates under Article IX of this Act. The Commission shall not, however, have the authority in a proceeding under this paragraph (3) to consider or order any changes to the structure or protocols of the energy efficiency formula rate approved under paragraph (2) of this subsection (d). In a proceeding under this paragraph (3), the Commission shall enter its order no later than the earlier of 195 days after the utility's filing of its annual update of cost inputs to the energy efficiency formula rate or December 15. The utility's proposed return on equity calculation, as described in paragraphs (7) through (9) of subsection (g) of this Section, shall be deemed the final, approved calculation on December 15 of the year in which it is filed unless the Commission enters an order on or before December 15, after notice and hearing, that modifies such calculation consistent with this Section. The Commission's determinations of the prudence and reasonableness of the costs incurred, and determination of such return on equity calculation, for the applicable calendar year shall be final upon entry of the Commission's order and shall not be subject to reopening, reexamination, or collateral attack in any other Commission proceeding, case, docket, order, rule, or regulation; however, nothing in this paragraph (3) shall prohibit a party from petitioning the Commission to rehear or appeal to the courts the order under the provisions of this Act.

(e) Beginning on June 1, 2017 (the effective date of Public Act 99-906), a utility subject to the requirements of this Section may elect to defer, as a regulatory asset, up to the full amount of its expenditures incurred under this Section for each annual period, including, but not limited to, any expenditures incurred above the funding level set by subsection (f) of this Section for a given year. The total expenditures deferred as a regulatory asset in a given year shall be amortized and recovered over a period that is equal to the weighted average of the energy efficiency measure lives implemented for that year that are reflected in the regulatory asset. The unamortized balance shall be recognized as of December 31 for a given year. The utility shall also earn a return on the total of the unamortized balances of all of the energy efficiency regulatory assets, less any deferred taxes related to those unamortized balances, at an annual rate equal to the utility's weighted average cost of capital that includes, based on a year-end capital structure, the utility's actual cost of debt for the applicable calendar year and a cost of equity, which shall be calculated as the sum of the (i) the average for the applicable calendar year of the monthly average yields of 30-year U.S. Treasury bonds published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication; and (ii) 580 basis points, including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return. Capital investment costs shall be depreciated and recovered over their useful lives consistent with generally accepted accounting principles. The weighted average cost of capital shall be applied to the capital investment cost balance, less any accumulated depreciation and accumulated deferred income taxes, as of December 31 for a given year.

When an electric utility creates a regulatory asset under the provisions of this Section, the costs are recovered over a period during which customers also receive a benefit which is in the public interest. Accordingly, it is the intent of the General Assembly that an electric utility that elects to create a regulatory asset under the provisions of this Section shall recover all of the associated costs as set forth in this Section. After the Commission has approved the prudence and reasonableness of the costs that comprise the regulatory asset, the electric utility shall be permitted to recover all such costs, and the value and recoverability through rates of the associated regulatory asset shall not be limited, altered, impaired, or reduced.

(f) Beginning in 2017, each electric utility shall file an energy efficiency plan with the Commission to meet the energy efficiency standards for the next applicable multi-year period beginning January 1 of the year following the filing, according to the schedule set forth in paragraphs (1) through (3) of this subsection (f). If a utility does not file such a plan on or before the applicable filing deadline for the plan, it shall face a penalty of $100,000 per day until the plan is filed.

(1) No later than 30 days after June 1, 2017 (the effective date of Public Act 99-906), each electric utility shall file a 4-year energy efficiency plan commencing on January 1, 2018 that is designed to achieve the cumulative persisting annual savings goals specified in paragraphs (1) through (4) of subsection (b-5) of this Section or in paragraphs (1) through (4) of subsection (b-15) of this Section, as applicable, through implementation of energy efficiency measures; however, the goals may be reduced if the utility's expenditures are limited pursuant to subsection (m) of this Section or, for a utility that serves less than 3,000,000 retail customers, if each of the following conditions are met: (A) the plan's analysis and forecasts of the utility's ability to acquire energy savings demonstrate that achievement of such goals is not cost effective; and (B) the amount of energy savings achieved by the utility as determined by the independent evaluator for the most recent year for which savings have been evaluated preceding the plan filing was less than the average annual amount of savings required to achieve the goals for the applicable 4-year plan period. Except as provided in subsection (m) of this Section, annual increases in cumulative persisting annual savings goals during the applicable 4-year plan period shall not be reduced to amounts that are less than the maximum amount of cumulative persisting annual savings that is forecast to be cost-effectively achievable during the 4-year plan period. The Commission shall review any proposed goal reduction as part of its review and approval of the utility's proposed plan.

(2) No later than March 1, 2021, each electric utility shall file a 4-year energy efficiency plan commencing on January 1, 2022 that is designed to achieve the cumulative persisting annual savings goals specified in paragraphs (5) through (8) of subsection (b-5) of this Section or in paragraphs (5) through (8) of subsection (b-15) of this Section, as applicable, through implementation of energy efficiency measures; however, the goals may be reduced if either (1) clear and convincing evidence demonstrates, through independent analysis, that the expenditure limits in subsection (m) of this Section preclude full achievement of the goals or (2) each of the following conditions are met: (A) the plan's analysis and forecasts of the utility's ability to acquire energy savings demonstrate by clear and convincing evidence and through independent analysis that achievement of such goals is not cost effective; and (B) the amount of energy savings achieved by the utility as determined by the independent evaluator for the most recent year for which savings have been evaluated preceding the plan filing was less than the average annual amount of savings required to achieve the goals for the applicable 4-year plan period. If there is not clear and convincing evidence that achieving the savings goals specified in paragraph (b-5) or (b-15) of this Section is possible both cost-effectively and within the expenditure limits in subsection (m), such savings goals shall not be reduced. Except as provided in subsection (m) of this Section, annual increases in cumulative persisting annual savings goals during the applicable 4-year plan period shall not be reduced to amounts that are less than the maximum amount of cumulative persisting annual savings that is forecast to be cost-effectively achievable during the 4-year plan period. The Commission shall review any proposed goal reduction as part of its review and approval of the utility's proposed plan.

(3) No later than March 1, 2025, each electric utility shall file a 4-year energy efficiency plan commencing on January 1, 2026 that is designed to achieve the cumulative persisting annual savings goals specified in paragraphs (9) through (12) of subsection (b-5) of this Section or in paragraphs (9) through (12) of subsection (b-15) of this Section, as applicable, through implementation of energy efficiency measures; however, the goals may be reduced if either (1) clear and convincing evidence demonstrates, through independent analysis, that the expenditure limits in subsection (m) of this Section preclude full achievement of the goals or (2) each of the following conditions are met: (A) the plan's analysis and forecasts of the utility's ability to acquire energy savings demonstrate by clear and convincing evidence and through independent analysis that achievement of such goals is not cost effective; and (B) the amount of energy savings achieved by the utility as determined by the independent evaluator for the most recent year for which savings have been evaluated preceding the plan filing was less than the average annual amount of savings required to achieve the goals for the applicable 4-year plan period. If there is not clear and convincing evidence that achieving the savings goals specified in paragraphs (b-5) or (b-15) of this Section is possible both cost-effectively and within the expenditure limits in subsection (m), such savings goals shall not be reduced. Except as provided in subsection (m) of this Section, annual increases in cumulative persisting annual savings goals during the applicable 4-year plan period shall not be reduced to amounts that are less than the maximum amount of cumulative persisting annual savings that is forecast to be cost-effectively achievable during the 4-year plan period. The Commission shall review any proposed goal reduction as part of its review and approval of the utility's proposed plan.

(4) No later than March 1, 2029, and every 4 years thereafter, each electric utility shall file a 4-year energy efficiency plan commencing on January 1, 2030, and every 4 years thereafter, respectively, that is designed to achieve the cumulative persisting annual savings goals established by the Illinois Commerce Commission pursuant to direction of subsections (b-5) and (b-15) of this Section, as applicable, through implementation of energy efficiency measures; however, the goals may be reduced if either (1) clear and convincing evidence and independent analysis demonstrates that the expenditure limits in subsection (m) of this Section preclude full achievement of the goals or (2) each of the following conditions are met: (A) the plan's analysis and forecasts of the utility's ability to acquire energy savings demonstrate by clear and convincing evidence and through independent analysis that achievement of such goals is not cost-effective; and (B) the amount of energy savings achieved by the utility as determined by the independent evaluator for the most recent year for which savings have been evaluated preceding the plan filing was less than the average annual amount of savings required to achieve the goals for the applicable 4-year plan period. If there is not clear and convincing evidence that achieving the savings goals specified in paragraphs (b-5) or (b-15) of this Section is possible both cost-effectively and within the expenditure limits in subsection (m), such savings goals shall not be reduced. Except as provided in subsection (m) of this Section, annual increases in cumulative persisting annual savings goals during the applicable 4-year plan period shall not be reduced to amounts that are less than the maximum amount of cumulative persisting annual savings that is forecast to be cost-effectively achievable during the 4-year plan period. The Commission shall review any proposed goal reduction as part of its review and approval of the utility's proposed plan.

Each utility's plan shall set forth the utility's proposals to meet the energy efficiency standards identified in subsection (b-5) or (b-15), as applicable and as such standards may have been modified under this subsection (f), taking into account the unique circumstances of the utility's service territory. For those plans commencing on January 1, 2018, the Commission shall seek public comment on the utility's plan and shall issue an order approving or disapproving each plan no later than 105 days after June 1, 2017 (the effective date of Public Act 99-906). For those plans commencing after December 31, 2021, the Commission shall seek public comment on the utility's plan and shall issue an order approving or disapproving each plan within 6 months after its submission. If the Commission disapproves a plan, the Commission shall, within 30 days, describe in detail the reasons for the disapproval and describe a path by which the utility may file a revised draft of the plan to address the Commission's concerns satisfactorily. If the utility does not refile with the Commission within 60 days, the utility shall be subject to penalties at a rate of $100,000 per day until the plan is filed. This process shall continue, and penalties shall accrue, until the utility has successfully filed a portfolio of energy efficiency and demand-response measures. Penalties shall be deposited into the Energy Efficiency Trust Fund.

(g) In submitting proposed plans and funding levels under subsection (f) of this Section to meet the savings goals identified in subsection (b-5) or (b-15) of this Section, as applicable, the utility shall:

(1) Demonstrate that its proposed energy efficiency measures will achieve the applicable requirements that are identified in subsection (b-5) or (b-15) of this Section, as modified by subsection (f) of this Section.

(2) (Blank).

(2.5) Demonstrate consideration of program options for (A) advancing new building codes, appliance standards, and municipal regulations governing existing and new building efficiency improvements and (B) supporting efforts to improve compliance with new building codes, appliance standards and municipal regulations, as potentially cost-effective means of acquiring energy savings to count toward savings goals.

(3) Demonstrate that its overall portfolio of measures, not including low-income programs described in subsection (c) of this Section, is cost-effective using the total resource cost test or complies with paragraphs (1) through (3) of subsection (f) of this Section and represents a diverse cross-section of opportunities for customers of all rate classes, other than those customers described in subsection (l) of this Section, to participate in the programs. Individual measures need not be cost effective.

(3.5) Demonstrate that the utility's plan integrates the delivery of energy efficiency programs with natural gas efficiency programs, programs promoting distributed solar, programs promoting demand response and other efforts to address bill payment issues, including, but not limited to, LIHEAP and the Percentage of Income Payment Plan, to the extent such integration is practical and has the potential to enhance customer engagement, minimize market confusion, or reduce administrative costs.

(4) Present a third-party energy efficiency implementation program subject to the following requirements:

(A) beginning with the year commencing January 1, 2019, electric utilities that serve more than 3,000,000 retail customers in the State shall fund third-party energy efficiency programs in an amount that is no less than $25,000,000 per year, and electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State shall fund third-party energy efficiency programs in an amount that is no less than $8,350,000 per year;

(B) during 2018, the utility shall conduct a solicitation process for purposes of requesting proposals from third-party vendors for those third-party energy efficiency programs to be offered during one or more of the years commencing January 1, 2019, January 1, 2020, and January 1, 2021; for those multi-year plans commencing on January 1, 2022 and January 1, 2026, the utility shall conduct a solicitation process during 2021 and 2025, respectively, for purposes of requesting proposals from third-party vendors for those third-party energy efficiency programs to be offered during one or more years of the respective multi-year plan period; for each solicitation process, the utility shall identify the sector, technology, or geographical area for which it is seeking requests for proposals; the solicitation process must be either for programs that fill gaps in the utility's program portfolio and for programs that target low-income customers, business sectors, building types, geographies, or other specific parts of its customer base with initiatives that would be more effective at reaching these customer segments than the utilities' programs filed in its energy efficiency plans;

(C) the utility shall propose the bidder qualifications, performance measurement process, and contract structure, which must include a performance payment mechanism and general terms and conditions; the proposed qualifications, process, and structure shall be subject to Commission approval; and

(D) the utility shall retain an independent third party to score the proposals received through the solicitation process described in this paragraph (4), rank them according to their cost per lifetime kilowatt-hours saved, and assemble the portfolio of third-party programs.

The electric utility shall recover all costs associated with Commission-approved, third-party administered programs regardless of the success of those programs.

(4.5) Implement cost-effective demand-response measures to reduce peak demand by 0.1% over the prior year for eligible retail customers, as defined in Section 16-111.5 of this Act, and for customers that elect hourly service from the utility pursuant to Section 16-107 of this Act, provided those customers have not been declared competitive. This requirement continues until December 31, 2026.

(5) Include a proposed or revised cost-recovery tariff mechanism, as provided for under subsection (d) of this Section, to fund the proposed energy efficiency and demand-response measures and to ensure the recovery of the prudently and reasonably incurred costs of Commission-approved programs.

(6) Provide for an annual independent evaluation of the performance of the cost-effectiveness of the utility's portfolio of measures, as well as a full review of the multi-year plan results of the broader net program impacts and, to the extent practical, for adjustment of the measures on a going-forward basis as a result of the evaluations. The resources dedicated to evaluation shall not exceed 3% of portfolio resources in any given year.

(7) For electric utilities that serve more than 3,000,000 retail customers in the State:

(A) Through December 31, 2025, provide for an adjustment to the return on equity component of the utility's weighted average cost of capital calculated under subsection (d) of this Section:

(i) If the independent evaluator determines that the utility achieved a cumulative persisting annual savings that is less than the applicable annual incremental goal, then the return on equity component shall be reduced by a maximum of 200 basis points in the event that the utility achieved no more than 75% of such goal. If the utility achieved more than 75% of the applicable annual incremental goal but less than 100% of such goal, then the return on equity component shall be reduced by 8 basis points for each percent by which the utility failed to achieve the goal.

(ii) If the independent evaluator determines that the utility achieved a cumulative persisting annual savings that is more than the applicable annual incremental goal, then the return on equity component shall be increased by a maximum of 200 basis points in the event that the utility achieved at least 125% of such goal. If the utility achieved more than 100% of the applicable annual incremental goal but less than 125% of such goal, then the return on equity component shall be increased by 8 basis points for each percent by which the utility achieved above the goal. If the applicable annual incremental goal was reduced under paragraph (1) or (2) of subsection (f) of this Section, then the following adjustments shall be made to the calculations described in this item (ii):

(aa) the calculation for determining achievement that is at least 125% of the applicable annual incremental goal shall use the unreduced applicable annual incremental goal to set the value; and

(bb) the calculation for determining achievement that is less than 125% but more than 100% of the applicable annual incremental goal shall use the reduced applicable annual incremental goal to set the value for 100% achievement of the goal and shall use the unreduced goal to set the value for 125% achievement. The 8 basis point value shall also be modified, as necessary, so that the 200 basis points are evenly apportioned among each percentage point value between 100% and 125% achievement.

(B) For the period January 1, 2026 through December 31, 2029 and in all subsequent 4-year periods, provide for an adjustment to the return on equity component of the utility's weighted average cost of capital calculated under subsection (d) of this Section:

(i) If the independent evaluator determines that the utility achieved a cumulative persisting annual savings that is less than the applicable annual incremental goal, then the return on equity component shall be reduced by a maximum of 200 basis points in the event that the utility achieved no more than 66% of such goal. If the utility achieved more than 66% of the applicable annual incremental goal but less than 100% of such goal, then the return on equity component shall be reduced by 6 basis points for each percent by which the utility failed to achieve the goal.

(ii) If the independent evaluator determines that the utility achieved a cumulative persisting annual savings that is more than the applicable annual incremental goal, then the return on equity component shall be increased by a maximum of 200 basis points in the event that the utility achieved at least 134% of such goal. If the utility achieved more than 100% of the applicable annual incremental goal but less than 134% of such goal, then the return on equity component shall be increased by 6 basis points for each percent by which the utility achieved above the goal. If the applicable annual incremental goal was reduced under paragraph (3) of subsection (f) of this Section, then the following adjustments shall be made to the calculations described in this item (ii):

(aa) the calculation for determining achievement that is at least 134% of the applicable annual incremental goal shall use the unreduced applicable annual incremental goal to set the value; and

(bb) the calculation for determining achievement that is less than 134% but more than 100% of the applicable annual incremental goal shall use the reduced applicable annual incremental goal to set the value for 100% achievement of the goal and shall use the unreduced goal to set the value for 134% achievement. The 6 basis point value shall also be modified, as necessary, so that the 200 basis points are evenly apportioned among each percentage point value between 100% and 134% achievement.

(C) Notwithstanding the provisions of subparagraphs (A) and (B) of this paragraph (7), if the applicable annual incremental goal for an electric utility is ever less than 0.6% of deemed average weather normalized sales of electric power and energy during calendar years 2014, 2015, and 2016, an adjustment to the return on equity component of the utility's weighted average cost of capital calculated under subsection (d) of this Section shall be made as follows:

(i) If the independent evaluator determines that the utility achieved a cumulative persisting annual savings that is less than would have been achieved had the applicable annual incremental goal been achieved, then the return on equity component shall be reduced by a maximum of 200 basis points if the utility achieved no more than 75% of its applicable annual total savings requirement as defined in paragraph (7.5) of this subsection. If the utility achieved more than 75% of the applicable annual total savings requirement but less than 100% of such goal, then the return on equity component shall be reduced by 8 basis points for each percent by which the utility failed to achieve the goal.

(ii) If the independent evaluator determines that the utility achieved a cumulative persisting annual savings that is more than would have been achieved had the applicable annual incremental goal been achieved, then the return on equity component shall be increased by a maximum of 200 basis points if the utility achieved at least 125% of its applicable annual total savings requirement. If the utility achieved more than 100% of the applicable annual total savings requirement but less than 125% of such goal, then the return on equity component shall be increased by 8 basis points for each percent by which the utility achieved above the applicable annual total savings requirement. If the applicable annual incremental goal was reduced under paragraph (1) or (2) of subsection (f) of this Section, then the following adjustments shall be made to the calculations described in this item (ii):

(aa) the calculation for determining achievement that is at least 125% of the applicable annual total savings requirement shall use the unreduced applicable annual incremental goal to set the value; and

(bb) the calculation for determining achievement that is less than 125% but more than 100% of the applicable annual total savings requirement shall use the reduced applicable annual incremental goal to set the value for 100% achievement of the goal and shall use the unreduced goal to set the value for 125% achievement. The 8 basis point value shall also be modified, as necessary, so that the 200 basis points are evenly apportioned among each percentage point value between 100% and 125% achievement.

(7.5) For purposes of this Section, the term "applicable annual incremental goal" means the difference between the cumulative persisting annual savings goal for the calendar year that is the subject of the independent evaluator's determination and the cumulative persisting annual savings goal for the immediately preceding calendar year, as such goals are defined in subsections (b-5) and (b-15) of this Section and as these goals may have been modified as provided for under subsection (b-20) and paragraphs (1) through (3) of subsection (f) of this Section. Under subsections (b), (b-5), (b-10), and (b-15) of this Section, a utility must first replace energy savings from measures that have expired before any progress towards achievement of its applicable annual incremental goal may be counted. Savings may expire because measures installed in previous years have reached the end of their lives, because measures installed in previous years are producing lower savings in the current year than in the previous year, or for other reasons identified by independent evaluators. Notwithstanding anything else set forth in this Section, the difference between the actual annual incremental savings achieved in any given year, including the replacement of energy savings that have expired, and the applicable annual incremental goal shall not affect adjustments to the return on equity for subsequent calendar years under this subsection (g).

In this Section, "applicable annual total savings requirement" means the total amount of new annual savings that the utility must achieve in any given year to achieve the applicable annual incremental goal. This is equal to the applicable annual incremental goal plus the total new annual savings that are required to replace savings that expired in or at the end of the previous year.

(8) For electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State:

(A) Through December 31, 2025, the applicable annual incremental goal shall be compared to the annual incremental savings as determined by the independent evaluator.

(i) The return on equity component shall be reduced by 8 basis points for each percent by which the utility did not achieve 84.4% of the applicable annual incremental goal.

(ii) The return on equity component shall be increased by 8 basis points for each percent by which the utility exceeded 100% of the applicable annual incremental goal.

(iii) The return on equity component shall not be increased or decreased if the annual incremental savings as determined by the independent evaluator is greater than 84.4% of the applicable annual incremental goal and less than 100% of the applicable annual incremental goal.

(iv) The return on equity component shall not be increased or decreased by an amount greater than 200 basis points pursuant to this subparagraph (A).

(B) For the period of January 1, 2026 through December 31, 2029 and in all subsequent 4-year periods, the applicable annual incremental goal shall be compared to the annual incremental savings as determined by the independent evaluator.

(i) The return on equity component shall be reduced by 6 basis points for each percent by which the utility did not achieve 100% of the applicable annual incremental goal.

(ii) The return on equity component shall be increased by 6 basis points for each percent by which the utility exceeded 100% of the applicable annual incremental goal.

(iii) The return on equity component shall not be increased or decreased by an amount greater than 200 basis points pursuant to this subparagraph (B).

(C) Notwithstanding provisions in subparagraphs (A) and (B) of paragraph (7) of this subsection, if the applicable annual incremental goal for an electric utility is ever less than 0.6% of deemed average weather normalized sales of electric power and energy during calendar years 2014, 2015 and 2016, an adjustment to the return on equity component of the utility's weighted average cost of capital calculated under subsection (d) of this Section shall be made as follows:

(i) The return on equity component shall be reduced by 8 basis points for each percent by which the utility did not achieve 100% of the applicable annual total savings requirement.

(ii) The return on equity component shall be increased by 8 basis points for each percent by which the utility exceeded 100% of the applicable annual total savings requirement.

(iii) The return on equity component shall not be increased or decreased by an amount greater than 200 basis points pursuant to this subparagraph (C).

(D) If the applicable annual incremental goal was reduced under paragraph (1), (2), (3), or (4) of subsection (f) of this Section, then the following adjustments shall be made to the calculations described in subparagraphs (A), (B), and (C) of this paragraph (8):

(i) The calculation for determining achievement that is at least 125% or 134%, as applicable, of the applicable annual incremental goal or the applicable annual total savings requirement, as applicable, shall use the unreduced applicable annual incremental goal to set the value.

(ii) For the period through December 31, 2025, the calculation for determining achievement that is less than 125% but more than 100% of the applicable annual incremental goal or the applicable annual total savings requirement, as applicable, shall use the reduced applicable annual incremental goal to set the value for 100% achievement of the goal and shall use the unreduced goal to set the value for 125% achievement. The 8 basis point value shall also be modified, as necessary, so that the 200 basis points are evenly apportioned among each percentage point value between 100% and 125% achievement.

(iii) For the period of January 1, 2026 through December 31, 2029 and all subsequent 4-year periods, the calculation for determining achievement that is less than 125% or 134%, as applicable, but more than 100% of the applicable annual incremental goal or the applicable annual total savings requirement, as applicable, shall use the reduced applicable annual incremental goal to set the value for 100% achievement of the goal and shall use the unreduced goal to set the value for 125% achievement. The 6 basis-point value or 8 basis-point value, as applicable, shall also be modified, as necessary, so that the 200 basis points are evenly apportioned among each percentage point value between 100% and 125% or between 100% and 134% achievement, as applicable.

(9) The utility shall submit the energy savings data to the independent evaluator no later than 30 days after the close of the plan year. The independent evaluator shall determine the cumulative persisting annual savings for a given plan year, as well as an estimate of job impacts and other macroeconomic impacts of the efficiency programs for that year, no later than 120 days after the close of the plan year. The utility shall submit an informational filing to the Commission no later than 160 days after the close of the plan year that attaches the independent evaluator's final report identifying the cumulative persisting annual savings for the year and calculates, under paragraph (7) or (8) of this subsection (g), as applicable, any resulting change to the utility's return on equity component of the weighted average cost of capital applicable to the next plan year beginning with the January monthly billing period and extending through the December monthly billing period. However, if the utility recovers the costs incurred under this Section under paragraphs (2) and (3) of subsection (d) of this Section, then the utility shall not be required to submit such informational filing, and shall instead submit the information that would otherwise be included in the informational filing as part of its filing under paragraph (3) of such subsection (d) that is due on or before June 1 of each year.

For those utilities that must submit the informational filing, the Commission may, on its own motion or by petition, initiate an investigation of such filing, provided, however, that the utility's proposed return on equity calculation shall be deemed the final, approved calculation on December 15 of the year in which it is filed unless the Commission enters an order on or before December 15, after notice and hearing, that modifies such calculation consistent with this Section.

The adjustments to the return on equity component described in paragraphs (7) and (8) of this subsection (g) shall be applied as described in such paragraphs through a separate tariff mechanism, which shall be filed by the utility under subsections (f) and (g) of this Section.

(9.5) The utility must demonstrate how it will ensure that program implementation contractors and energy efficiency installation vendors will promote workforce equity and quality jobs.

(9.6) Utilities shall collect data necessary to ensure compliance with paragraph (9.5) no less than quarterly and shall communicate progress toward compliance with paragraph (9.5) to program implementation contractors and energy efficiency installation vendors no less than quarterly. Utilities shall work with relevant vendors, providing education, training, and other resources needed to ensure compliance and, where necessary, adjusting or terminating work with vendors that cannot assist with compliance.

(10) Utilities required to implement efficiency programs under subsections (b-5) and (b-10) shall report annually to the Illinois Commerce Commission and the General Assembly on how hiring, contracting, job training, and other practices related to its energy efficiency programs enhance the diversity of vendors working on such programs. These reports must include data on vendor and employee diversity, including data on the implementation of paragraphs (9.5) and (9.6). If the utility is not meeting the requirements of paragraphs (9.5) and (9.6), the utility shall submit a plan to adjust their activities so that they meet the requirements of paragraphs (9.5) and (9.6) within the following year.

(h) No more than 4% of energy efficiency and demand-response program revenue may be allocated for research, development, or pilot deployment of new equipment or measures. Electric utilities shall work with interested stakeholders to formulate a plan for how these funds should be spent, incorporate statewide approaches for these allocations, and file a 4-year plan that demonstrates that collaboration. If a utility files a request for modified annual energy savings goals with the Commission, then a utility shall forgo spending portfolio dollars on research and development proposals.

(i) When practicable, electric utilities shall incorporate advanced metering infrastructure data into the planning, implementation, and evaluation of energy efficiency measures and programs, subject to the data privacy and confidentiality protections of applicable law.

(j) The independent evaluator shall follow the guidelines and use the savings set forth in Commission-approved energy efficiency policy manuals and technical reference manuals, as each may be updated from time to time. Until such time as measure life values for energy efficiency measures implemented for low-income households under subsection (c) of this Section are incorporated into such Commission-approved manuals, the low-income measures shall have the same measure life values that are established for same measures implemented in households that are not low-income households.

(k) Notwithstanding any provision of law to the contrary, an electric utility subject to the requirements of this Section may file a tariff cancelling an automatic adjustment clause tariff in effect under this Section or Section 8-103, which shall take effect no later than one business day after the date such tariff is filed. Thereafter, the utility shall be authorized to defer and recover its expenditures incurred under this Section through a new tariff authorized under subsection (d) of this Section or in the utility's next rate case under Article IX or Section 16-108.5 of this Act, with interest at an annual rate equal to the utility's weighted average cost of capital as approved by the Commission in such case. If the utility elects to file a new tariff under subsection (d) of this Section, the utility may file the tariff within 10 days after June 1, 2017 (the effective date of Public Act 99-906), and the cost inputs to such tariff shall be based on the projected costs to be incurred by the utility during the calendar year in which the new tariff is filed and that were not recovered under the tariff that was cancelled as provided for in this subsection. Such costs shall include those incurred or to be incurred by the utility under its multi-year plan approved under subsections (f) and (g) of this Section, including, but not limited to, projected capital investment costs and projected regulatory asset balances with correspondingly updated depreciation and amortization reserves and expense. The Commission shall, after notice and hearing, approve, or approve with modification, such tariff and cost inputs no later than 75 days after the utility filed the tariff, provided that such approval, or approval with modification, shall be consistent with the provisions of this Section to the extent they do not conflict with this subsection (k). The tariff approved by the Commission shall take effect no later than 5 days after the Commission enters its order approving the tariff.

No later than 60 days after the effective date of the tariff cancelling the utility's automatic adjustment clause tariff, the utility shall file a reconciliation that reconciles the moneys collected under its automatic adjustment clause tariff with the costs incurred during the period beginning June 1, 2016 and ending on the date that the electric utility's automatic adjustment clause tariff was cancelled. In the event the reconciliation reflects an under-collection, the utility shall recover the costs as specified in this subsection (k). If the reconciliation reflects an over-collection, the utility shall apply the amount of such over-collection as a one-time credit to retail customers' bills.

(l) For the calendar years covered by a multi-year plan commencing after December 31, 2017, subsections (a) through (j) of this Section do not apply to eligible large private energy customers that have chosen to opt out of multi-year plans consistent with this subsection (1).

(1) For purposes of this subsection (l), "eligible large private energy customer" means any retail customers, except for federal, State, municipal, and other public customers, of an electric utility that serves more than 3,000,000 retail customers, except for federal, State, municipal and other public customers, in the State and whose total highest 30 minute demand was more than 10,000 kilowatts, or any retail customers of an electric utility that serves less than 3,000,000 retail customers but more than 500,000 retail customers in the State and whose total highest 15 minute demand was more than 10,000 kilowatts. For purposes of this subsection (l), "retail customer" has the meaning set forth in Section 16-102 of this Act. However, for a business entity with multiple sites located in the State, where at least one of those sites qualifies as an eligible large private energy customer, then any of that business entity's sites, properly identified on a form for notice, shall be considered eligible large private energy customers for the purposes of this subsection (l). A determination of whether this subsection is applicable to a customer shall be made for each multi-year plan beginning after December 31, 2017. The criteria for determining whether this subsection (l) is applicable to a retail customer shall be based on the 12 consecutive billing periods prior to the start of the first year of each such multi-year plan.

(2) Within 45 days after September 15, 2021 (the effective date of Public Act 102-662), the Commission shall prescribe the form for notice required for opting out of energy efficiency programs. The notice must be submitted to the retail electric utility 12 months before the next energy efficiency planning cycle. However, within 120 days after the Commission's initial issuance of the form for notice, eligible large private energy customers may submit a form for notice to an electric utility. The form for notice for opting out of energy efficiency programs shall include all of the following:

(A) a statement indicating that the customer has elected to opt out;

(B) the account numbers for the customer accounts to which the opt out shall apply;

(C) the mailing address associated with the customer accounts identified under subparagraph (B);

(D) an American Society of Heating, Refrigerating, and Air-Conditioning Engineers (ASHRAE) level 2 or higher audit report conducted by an independent third-party expert identifying cost-effective energy efficiency project opportunities that could be invested in over the next 10 years. A retail customer with specialized processes may utilize a self-audit process in lieu of the ASHRAE audit;

(E) a description of the customer's plans to reallocate the funds toward internal energy efficiency efforts identified in the subparagraph (D) report, including, but not limited to: (i) strategic energy management or other programs, including descriptions of targeted buildings, equipment and operations; (ii) eligible energy efficiency measures; and (iii) expected energy savings, itemized by technology. If the subparagraph (D) audit report identifies that the customer currently utilizes the best available energy efficient technology, equipment, programs, and operations, the customer may provide a statement that more efficient technology, equipment, programs, and operations are not reasonably available as a means of satisfying this subparagraph (E); and

(F) the effective date of the opt out, which will be the next January 1 following notice of the opt out.

(3) Upon receipt of a properly and timely noticed request for opt out submitted by an eligible large private energy customer, the retail electric utility shall grant the request, file the request with the Commission and, beginning January 1 of the following year, the opted out customer shall no longer be assessed the costs of the plan and shall be prohibited from participating in that 4-year plan cycle to give the retail utility the certainty to design program plan proposals.

(4) Upon a customer's election to opt out under paragraphs (1) and (2) of this subsection (l) and commencing on the effective date of said opt out, the account properly identified in the customer's notice under paragraph (2) shall not be subject to any cost recovery and shall not be eligible to participate in, or directly benefit from, compliance with energy efficiency cumulative persisting savings requirements under subsections (a) through (j).

(5) A utility's cumulative persisting annual savings targets will exclude any opted out load.

(6) The request to opt out is only valid for the requested plan cycle. An eligible large private energy customer must also request to opt out for future energy plan cycles, otherwise the customer will be included in the future energy plan cycle.

(m) Notwithstanding the requirements of this Section, as part of a proceeding to approve a multi-year plan under subsections (f) and (g) of this Section if the multi-year plan has been designed to maximize savings, but does not meet the cost cap limitations of this Section, the Commission shall reduce the amount of energy efficiency measures implemented for any single year, and whose costs are recovered under subsection (d) of this Section, by an amount necessary to limit the estimated average net increase due to the cost of the measures to no more than

(1) 3.5% for each of the 4 years beginning January 1, 2018,

(2) (blank),

(3) 4% for each of the 4 years beginning January 1, 2022,

(4) 4.25% for the 4 years beginning January 1, 2026, and

(5) 4.25% plus an increase sufficient to account for the rate of inflation between January 1, 2026 and January 1 of the first year of each subsequent 4-year plan cycle,

of the average amount paid per kilowatthour by residential eligible retail customers during calendar year 2015. An electric utility may plan to spend up to 10% more in any year during an applicable multi-year plan period to cost-effectively achieve additional savings so long as the average over the applicable multi-year plan period does not exceed the percentages defined in items (1) through (5). To determine the total amount that may be spent by an electric utility in any single year, the applicable percentage of the average amount paid per kilowatthour shall be multiplied by the total amount of energy delivered by such electric utility in the calendar year 2015, adjusted to reflect the proportion of the utility's load attributable to customers that have opted out of subsections (a) through (j) of this Section under subsection (l) of this Section. For purposes of this subsection (m), the amount paid per kilowatthour includes, without limitation, estimated amounts paid for supply, transmission, distribution, surcharges, and add-on taxes. For purposes of this Section, "eligible retail customers" shall have the meaning set forth in Section 16-111.5 of this Act. Once the Commission has approved a plan under subsections (f) and (g) of this Section, no subsequent rate impact determinations shall be made.

(n) A utility shall take advantage of the efficiencies available through existing Illinois Home Weatherization Assistance Program infrastructure and services, such as enrollment, marketing, quality assurance and implementation, which can reduce the need for similar services at a lower cost than utility-only programs, subject to capacity constraints at community action agencies, for both single-family and multifamily weatherization services, to the extent Illinois Home Weatherization Assistance Program community action agencies provide multifamily services. A utility's plan shall demonstrate that in formulating annual weatherization budgets, it has sought input and coordination with community action agencies regarding agencies' capacity to expand and maximize Illinois Home Weatherization Assistance Program delivery using the ratepayer dollars collected under this Section.

(Source: P.A. 102-662, eff. 9-15-21; 103-154, eff. 6-30-23; 103-613, eff. 7-1-24.)

(220 ILCS 5/8-104)

Sec. 8-104. Natural gas energy efficiency programs.

(a) It is the policy of the State that natural gas utilities and the Department of Commerce and Economic Opportunity are required to use cost-effective energy efficiency to reduce direct and indirect costs to consumers. It serves the public interest to allow natural gas utilities to recover costs for reasonably and prudently incurred expenses for cost-effective energy efficiency measures.

(b) For purposes of this Section, "energy efficiency" means measures that reduce the amount of energy required to achieve a given end use. "Energy efficiency" also includes measures that reduce the total Btus of electricity and natural gas needed to meet the end use or uses. "Cost-effective" means that the measures satisfy the total resource cost test which, for purposes of this Section, means a standard that is met if, for an investment in energy efficiency, the benefit-cost ratio is greater than one. The benefit-cost ratio is the ratio of the net present value of the total benefits of the measures to the net present value of the total costs as calculated over the lifetime of the measures. The total resource cost test compares the sum of avoided natural gas utility costs, representing the benefits that accrue to the system and the participant in the delivery of those efficiency measures, as well as other quantifiable societal benefits, including avoided electric utility costs, to the sum of all incremental costs of end use measures (including both utility and participant contributions), plus costs to administer, deliver, and evaluate each demand-side measure, to quantify the net savings obtained by substituting demand-side measures for supply resources. In calculating avoided costs, reasonable estimates shall be included for financial costs likely to be imposed by future regulation of emissions of greenhouse gases. The low-income programs described in item (4) of subsection (f) of this Section shall not be required to meet the total resource cost test.

(c) Natural gas utilities shall implement cost-effective energy efficiency measures to meet at least the following natural gas savings requirements, which shall be based upon the total amount of gas delivered to retail customers, other than the customers described in subsection (m) of this Section, during calendar year 2009 multiplied by the applicable percentage. Natural gas utilities may comply with this Section by meeting the annual incremental savings goal in the applicable year or by showing that total cumulative annual savings within a multi-year planning period associated with measures implemented after May 31, 2011 were equal to the sum of each annual incremental savings requirement from the first day of the multi-year planning period through the last day of the multi-year planning period:

(1) 0.2% by May 31, 2012;

(2) an additional 0.4% by May 31, 2013, increasing total savings to .6%;

(3) an additional 0.6% by May 31, 2014, increasing total savings to 1.2%;

(4) an additional 0.8% by May 31, 2015, increasing total savings to 2.0%;

(5) an additional 1% by May 31, 2016, increasing total savings to 3.0%;

(6) an additional 1.2% by May 31, 2017, increasing total savings to 4.2%;

(7) an additional 1.4% in the year commencing January 1, 2018;

(8) an additional 1.5% in the year commencing January 1, 2019; and

(9) an additional 1.5% in each 12-month period thereafter.

(d) Notwithstanding the requirements of subsection (c) of this Section, a natural gas utility shall limit the amount of energy efficiency implemented in any multi-year reporting period established by subsection (f) of Section 8-104 of this Act, by an amount necessary to limit the estimated average increase in the amounts paid by retail customers in connection with natural gas service to no more than 2% in the applicable multi-year reporting period. The energy savings requirements in subsection (c) of this Section may be reduced by the Commission for the subject plan, if the utility demonstrates by substantial evidence that it is highly unlikely that the requirements could be achieved without exceeding the applicable spending limits in any multi-year reporting period. No later than September 1, 2013, the Commission shall review the limitation on the amount of energy efficiency measures implemented pursuant to this Section and report to the General Assembly, in the report required by subsection (k) of this Section, its findings as to whether that limitation unduly constrains the procurement of energy efficiency measures.

(e) The provisions of this subsection (e) apply to those multi-year plans that commence prior to January 1, 2018. The utility shall utilize 75% of the available funding associated with energy efficiency programs approved by the Commission, and may outsource various aspects of program development and implementation. The remaining 25% of available funding shall be used by the Department of Commerce and Economic Opportunity to implement energy efficiency measures that achieve no less than 20% of the requirements of subsection (c) of this Section. Such measures shall be designed in conjunction with the utility and approved by the Commission. The Department may outsource development and implementation of energy efficiency measures. A minimum of 10% of the entire portfolio of cost-effective energy efficiency measures shall be procured from local government, municipal corporations, school districts, public institutions of higher education, and community college districts. Five percent of the entire portfolio of cost-effective energy efficiency measures may be granted to local government and municipal corporations for market transformation initiatives. The Department shall coordinate the implementation of these measures and shall integrate delivery of natural gas efficiency programs with electric efficiency programs delivered pursuant to Section 8-103 of this Act, unless the Department can show that integration is not feasible.

The apportionment of the dollars to cover the costs to implement the Department's share of the portfolio of energy efficiency measures shall be made to the Department once the Department has executed rebate agreements, grants, or contracts for energy efficiency measures and provided supporting documentation for those rebate agreements, grants, and contracts to the utility. The Department is authorized to adopt any rules necessary and prescribe procedures in order to ensure compliance by applicants in carrying out the purposes of rebate agreements for energy efficiency measures implemented by the Department made under this Section.

The details of the measures implemented by the Department shall be submitted by the Department to the Commission in connection with the utility's filing regarding the energy efficiency measures that the utility implements.

The portfolio of measures, administered by both the utilities and the Department, shall, in combination, be designed to achieve the annual energy savings requirements set forth in subsection (c) of this Section, as modified by subsection (d) of this Section.

The utility and the Department shall agree upon a reasonable portfolio of measures and determine the measurable corresponding percentage of the savings goals associated with measures implemented by the Department.

No utility shall be assessed a penalty under subsection (f) of this Section for failure to make a timely filing if that failure is the result of a lack of agreement with the Department with respect to the allocation of responsibilities or related costs or target assignments. In that case, the Department and the utility shall file their respective plans with the Commission and the Commission shall determine an appropriate division of measures and programs that meets the requirements of this Section.

(e-5) The provisions of this subsection (e-5) shall be applicable to those multi-year plans that commence after December 31, 2017. Natural gas utilities shall be responsible for overseeing the design, development, and filing of their efficiency plans with the Commission and may outsource development and implementation of energy efficiency measures. A minimum of 10% of the entire portfolio of cost-effective energy efficiency measures shall be procured from local government, municipal corporations, school districts, public institutions of higher education, and community college districts. Five percent of the entire portfolio of cost-effective energy efficiency measures may be granted to local government and municipal corporations for market transformation initiatives.

The utilities shall also present a portfolio of energy efficiency measures proportionate to the share of total annual utility revenues in Illinois from households at or below 150% of the poverty level. Such programs shall be targeted to households with incomes at or below 80% of area median income.

(e-10) A utility providing approved energy efficiency measures in this State shall be permitted to recover costs of those measures through an automatic adjustment clause tariff filed with and approved by the Commission. The tariff shall be established outside the context of a general rate case and shall be applicable to the utility's customers other than the customers described in subsection (m) of this Section. Each year the Commission shall initiate a review to reconcile any amounts collected with the actual costs and to determine the required adjustment to the annual tariff factor to match annual expenditures.

(e-15) For those multi-year plans that commence prior to January 1, 2018, each utility shall include, in its recovery of costs, the costs estimated for both the utility's and the Department's implementation of energy efficiency measures. Costs collected by the utility for measures implemented by the Department shall be submitted to the Department pursuant to Section 605-323 of the Civil Administrative Code of Illinois, shall be deposited into the Energy Efficiency Portfolio Standards Fund, and shall be used by the Department solely for the purpose of implementing these measures. A utility shall not be required to advance any moneys to the Department but only to forward such funds as it has collected. The Department shall report to the Commission on an annual basis regarding the costs actually incurred by the Department in the implementation of the measures. Any changes to the costs of energy efficiency measures as a result of plan modifications shall be appropriately reflected in amounts recovered by the utility and turned over to the Department.

(f) No later than October 1, 2010, each gas utility shall file an energy efficiency plan with the Commission to meet the energy efficiency standards through May 31, 2014. No later than October 1, 2013, each gas utility shall file an energy efficiency plan with the Commission to meet the energy efficiency standards through May 31, 2017. Beginning in 2017 and every 4 years thereafter, each utility shall file an energy efficiency plan with the Commission to meet the energy efficiency standards for the next applicable 4-year period beginning January 1 of the year following the filing. For those multi-year plans commencing on January 1, 2018, each utility shall file its proposed energy efficiency plan no later than 30 days after the effective date of this amendatory Act of the 99th General Assembly or May 1, 2017, whichever is later. Beginning in 2021 and every 4 years thereafter, each utility shall file its energy efficiency plan no later than March 1. If a utility does not file such a plan on or before the applicable filing deadline for the plan, then it shall face a penalty of $100,000 per day until the plan is filed.

Each utility's plan shall set forth the utility's proposals to meet the utility's portion of the energy efficiency standards identified in subsection (c) of this Section, as modified by subsection (d) of this Section, taking into account the unique circumstances of the utility's service territory. For those plans commencing after December 31, 2021, the Commission shall seek public comment on the utility's plan and shall issue an order approving or disapproving each plan within 6 months after its submission. For those plans commencing on January 1, 2018, the Commission shall seek public comment on the utility's plan and shall issue an order approving or disapproving each plan no later than August 31, 2017, or 105 days after the effective date of this amendatory Act of the 99th General Assembly, whichever is later. If the Commission disapproves a plan, the Commission shall, within 30 days, describe in detail the reasons for the disapproval and describe a path by which the utility may file a revised draft of the plan to address the Commission's concerns satisfactorily. If the utility does not refile with the Commission within 60 days after the disapproval, the utility shall be subject to penalties at a rate of $100,000 per day until the plan is filed. This process shall continue, and penalties shall accrue, until the utility has successfully filed a portfolio of energy efficiency measures. Penalties shall be deposited into the Energy Efficiency Trust Fund and the cost of any such penalties may not be recovered from ratepayers. In submitting proposed energy efficiency plans and funding levels to meet the savings goals adopted by this Act the utility shall:

(1) Demonstrate that its proposed energy efficiency measures will achieve the requirements that are identified in subsection (c) of this Section, as modified by subsection (d) of this Section.

(2) Present specific proposals to implement new building and appliance standards that have been placed into effect.

(3) Present estimates of the total amount paid for gas service expressed on a per therm basis associated with the proposed portfolio of measures designed to meet the requirements that are identified in subsection (c) of this Section, as modified by subsection (d) of this Section.

(4) For those multi-year plans that commence prior to January 1, 2018, coordinate with the Department to present a portfolio of energy efficiency measures proportionate to the share of total annual utility revenues in Illinois from households at or below 150% of the poverty level. Such programs shall be targeted to households with incomes at or below 80% of area median income.

(5) Demonstrate that its overall portfolio of energy efficiency measures, not including low-income programs described in item (4) of this subsection (f) and subsection (e-5) of this Section, are cost-effective using the total resource cost test and represent a diverse cross section of opportunities for customers of all rate classes to participate in the programs.

(6) Demonstrate that a gas utility affiliated with an electric utility that is required to comply with Section 8-103 or 8-103B of this Act has integrated gas and electric efficiency measures into a single program that reduces program or participant costs and appropriately allocates costs to gas and electric ratepayers. For those multi-year plans that commence prior to January 1, 2018, the Department shall integrate all gas and electric programs it delivers in any such utilities' service territories, unless the Department can show that integration is not feasible or appropriate.

(7) Include a proposed cost recovery tariff mechanism to fund the proposed energy efficiency measures and to ensure the recovery of the prudently and reasonably incurred costs of Commission-approved programs.

(8) Provide for quarterly status reports tracking implementation of and expenditures for the utility's portfolio of measures and, if applicable, the Department's portfolio of measures, an annual independent review, and a full independent evaluation of the multi-year results of the performance and the cost-effectiveness of the utility's and, if applicable, Department's portfolios of measures and broader net program impacts and, to the extent practical, for adjustment of the measures on a going forward basis as a result of the evaluations. The resources dedicated to evaluation shall not exceed 3% of portfolio resources in any given multi-year period.

(g) No more than 3% of expenditures on energy efficiency measures may be allocated for demonstration of breakthrough equipment and devices.

(h) Illinois natural gas utilities that are affiliated by virtue of a common parent company may, at the utilities' request, be considered a single natural gas utility for purposes of complying with this Section.

(i) If, after 3 years, a gas utility fails to meet the efficiency standard specified in subsection (c) of this Section as modified by subsection (d), then it shall make a contribution to the Low-Income Home Energy Assistance Program. The total liability for failure to meet the goal shall be assessed as follows:

(1) a large gas utility shall pay $600,000;

(2) a medium gas utility shall pay $400,000; and

(3) a small gas utility shall pay $200,000.

For purposes of this Section, (i) a "large gas utility" is a gas utility that on December 31, 2008, served more than 1,500,000 gas customers in Illinois; (ii) a "medium gas utility" is a gas utility that on December 31, 2008, served fewer than 1,500,000, but more than 500,000 gas customers in Illinois; and (iii) a "small gas utility" is a gas utility that on December 31, 2008, served fewer than 500,000 and more than 100,000 gas customers in Illinois. The costs of this contribution may not be recovered from ratepayers.

If a gas utility fails to meet the efficiency standard specified in subsection (c) of this Section, as modified by subsection (d) of this Section, in any 2 consecutive multi-year planning periods, then the responsibility for implementing the utility's energy efficiency measures shall be transferred to an independent program administrator selected by the Commission. Reasonable and prudent costs incurred by the independent program administrator to meet the efficiency standard specified in subsection (c) of this Section, as modified by subsection (d) of this Section, may be recovered from the customers of the affected gas utilities, other than customers described in subsection (m) of this Section. The utility shall provide the independent program administrator with all information and assistance necessary to perform the program administrator's duties including but not limited to customer, account, and energy usage data, and shall allow the program administrator to include inserts in customer bills. The utility may recover reasonable costs associated with any such assistance.

(j) No utility shall be deemed to have failed to meet the energy efficiency standards to the extent any such failure is due to a failure of the Department.

(k) Not later than January 1, 2012, the Commission shall develop and solicit public comment on a plan to foster statewide coordination and consistency between statutorily mandated natural gas and electric energy efficiency programs to reduce program or participant costs or to improve program performance. Not later than September 1, 2013, the Commission shall issue a report to the General Assembly containing its findings and recommendations.

(l) This Section does not apply to a gas utility that on January 1, 2009, provided gas service to fewer than 100,000 customers in Illinois.

(m) Subsections (a) through (k) of this Section do not apply to customers of a natural gas utility that have a North American Industry Classification System code number that is 22111 or any such code number beginning with the digits 31, 32, or 33 and (i) annual usage in the aggregate of 4 million therms or more within the service territory of the affected gas utility or with aggregate usage of 8 million therms or more in this State and complying with the provisions of item (l) of this subsection (m); or (ii) using natural gas as feedstock and meeting the usage requirements described in item (i) of this subsection (m), to the extent such annual feedstock usage is greater than 60% of the customer's total annual usage of natural gas.

(1) Customers described in this subsection (m) of this Section shall apply, on a form approved on or before October 1, 2009 by the Department, to the Department to be designated as a self-directing customer ("SDC") or as an exempt customer using natural gas as a feedstock from which other products are made, including, but not limited to, feedstock for a hydrogen plant, on or before the 1st day of February, 2010. Thereafter, application may be made not less than 6 months before the filing date of the gas utility energy efficiency plan described in subsection (f) of this Section; however, a new customer that commences taking service from a natural gas utility after February 1, 2010 may apply to become a SDC or exempt customer up to 30 days after beginning service. Customers described in this subsection (m) that have not already been approved by the Department may apply to be designated a self-directing customer or exempt customer, on a form approved by the Department, between September 1, 2013 and September 30, 2013. Customer applications that are approved by the Department under this amendatory Act of the 98th General Assembly shall be considered to be a self-directing customer or exempt customer, as applicable, for the current 3-year planning period effective December 1, 2013. Such application shall contain the following:

(A) the customer's certification that, at the time of its application, it qualifies to be a SDC or exempt customer described in this subsection (m) of this Section;

(B) in the case of a SDC, the customer's certification that it has established or will establish by the beginning of the utility's multi-year planning period commencing subsequent to the application, and will maintain for accounting purposes, an energy efficiency reserve account and that the customer will accrue funds in said account to be held for the purpose of funding, in whole or in part, energy efficiency measures of the customer's choosing, which may include, but are not limited to, projects involving combined heat and power systems that use the same energy source both for the generation of electrical or mechanical power and the production of steam or another form of useful thermal energy or the use of combustible gas produced from biomass, or both;

(C) in the case of a SDC, the customer's certification that annual funding levels for the energy efficiency reserve account will be equal to 2% of the customer's cost of natural gas, composed of the customer's commodity cost and the delivery service charges paid to the gas utility, or $150,000, whichever is less;

(D) in the case of a SDC, the customer's certification that the required reserve account balance will be capped at 3 years' worth of accruals and that the customer may, at its option, make further deposits to the account to the extent such deposit would increase the reserve account balance above the designated cap level;

(E) in the case of a SDC, the customer's certification that by October 1 of each year, beginning no sooner than October 1, 2012, the customer will report to the Department information, for the 12-month period ending May 31 of the same year, on all deposits and reductions, if any, to the reserve account during the reporting year, and to the extent deposits to the reserve account in any year are in an amount less than $150,000, the basis for such reduced deposits; reserve account balances by month; a description of energy efficiency measures undertaken by the customer and paid for in whole or in part with funds from the reserve account; an estimate of the energy saved, or to be saved, by the measure; and that the report shall include a verification by an officer or plant manager of the customer or by a registered professional engineer or certified energy efficiency trade professional that the funds withdrawn from the reserve account were used for the energy efficiency measures;

(F) in the case of an exempt customer, the customer's certification of the level of gas usage as feedstock in the customer's operation in a typical year and that it will provide information establishing this level, upon request of the Department;

(G) in the case of either an exempt customer or a SDC, the customer's certification that it has provided the gas utility or utilities serving the customer with a copy of the application as filed with the Department;

(H) in the case of either an exempt customer or a SDC, certification of the natural gas utility or utilities serving the customer in Illinois including the natural gas utility accounts that are the subject of the application; and

(I) in the case of either an exempt customer or a SDC, a verification signed by a plant manager or an authorized corporate officer attesting to the truthfulness and accuracy of the information contained in the application.

(2) The Department shall review the application to determine that it contains the information described in provisions (A) through (I) of item (1) of this subsection (m), as applicable. The review shall be completed within 30 days after the date the application is filed with the Department. Absent a determination by the Department within the 30-day period, the applicant shall be considered to be a SDC or exempt customer, as applicable, for all subsequent multi-year planning periods, as of the date of filing the application described in this subsection (m). If the Department determines that the application does not contain the applicable information described in provisions (A) through (I) of item (1) of this subsection (m), it shall notify the customer, in writing, of its determination that the application does not contain the required information and identify the information that is missing, and the customer shall provide the missing information within 15 working days after the date of receipt of the Department's notification.

(3) The Department shall have the right to audit the information provided in the customer's application and annual reports to ensure continued compliance with the requirements of this subsection. Based on the audit, if the Department determines the customer is no longer in compliance with the requirements of items (A) through (I) of item (1) of this subsection (m), as applicable, the Department shall notify the customer in writing of the noncompliance. The customer shall have 30 days to establish its compliance, and failing to do so, may have its status as a SDC or exempt customer revoked by the Department. The Department shall treat all information provided by any customer seeking SDC status or exemption from the provisions of this Section as strictly confidential.

(4) Upon request, or on its own motion, the Commission may open an investigation, no more than once every 3 years and not before October 1, 2014, to evaluate the effectiveness of the self-directing program described in this subsection (m).

Customers described in this subsection (m) that applied to the Department on January 3, 2013, were approved by the Department on February 13, 2013 to be a self-directing customer or exempt customer, and receive natural gas from a utility that provides gas service to at least 500,000 retail customers in Illinois and electric service to at least 1,000,000 retail customers in Illinois shall be considered to be a self-directing customer or exempt customer, as applicable, for the current 3-year planning period effective December 1, 2013.

(n) The applicability of this Section to customers described in subsection (m) of this Section is conditioned on the existence of the SDC program. In no event will any provision of this Section apply to such customers after January 1, 2020.

(o) Utilities' 3-year energy efficiency plans approved by the Commission on or before the effective date of this amendatory Act of the 99th General Assembly for the period June 1, 2014 through May 31, 2017 shall continue to be in force and effect through December 31, 2017 so that the energy efficiency programs set forth in those plans continue to be offered during the period June 1, 2017 through December 31, 2017. Each utility is authorized to increase, on a pro rata basis, the energy savings goals and budgets approved in its plan to reflect the additional 7 months of the plan's operation.

(Source: P.A. 103-613, eff. 7-1-24.)

(220 ILCS 5/8-105)

Sec. 8-105. (Repealed).

(Source: P.A. 96-33, eff. 7-10-09. Repealed internally, eff. 12-31-11.)

(220 ILCS 5/8-201) (from Ch. 111 2/3, par. 8-201)

Sec. 8-201. It is the policy of this State that no person should be denied essential utility service during the winter months due to financial inability to pay. It is also the policy of this State that public utilities and residential heating customers deal with each other in good faith and fair manner.

(Source: P.A. 84-617.)

(220 ILCS 5/8-201.4)

Sec. 8-201.4. Prohibition on use of utility name or logo by non-utility entity. No non-utility individual, business, or entity shall use a public utility name or logo, in whole or in part, in any manner to market, solicit, sell, or bill for a home insurance, maintenance, or warranty product. This prohibition does not apply to activities permitted to implement a program or plan approved by the Commission pursuant to an order entered under this Act. This prohibition does not apply to the partial use by a non-utility entity of a logo belonging to an electric utility that serves fewer than 200,000 customers in this State.

(Source: P.A. 102-928, eff. 1-1-23; 103-154, eff. 6-30-23.)

(220 ILCS 5/8-201.5)

Sec. 8-201.5. Military personnel in military service; no stoppage of gas or electricity; arrearage.

(a) In this Section:

"Military service" means any full-time training or duty, no matter how described under federal or State law, for which a service member is ordered to report by the President, Governor of a state, commonwealth, or territory of the United States, or other appropriate military authority.

"Service member" means a resident of Illinois who is a member of any component of the U.S. Armed Forces or the National Guard of any state, the District of Columbia, a commonwealth, or a territory of the United States.

(b) No company or electric cooperative shall for nonpayment stop gas or electricity from entering the residential premises that was the primary residence of a service member immediately before the service member was assigned to military service.

(c) In order to be eligible for the benefits granted to service members under this Section, a service member must provide the company or electric cooperative with a copy of the orders calling the service member to military service in excess of 29 consecutive days and of any orders further extending the service member's period of service.

(d) Upon the return from military service of a residential consumer who is a service member, the company or electric cooperative shall offer the residential consumer a period equal to at least the period of military service to pay any arrearages incurred during the period of the residential consumer's military service. The company or electric cooperative shall inform the residential consumer that, if the period that the company or electric cooperative offers presents a hardship to the consumer, the consumer may request a longer period to pay the arrearages and, in the case of a company that is a public utility, may request the assistance of the Illinois Commerce Commission to obtain a longer period. No late payment fees or interest shall be charged to the residential consumer during the period of military service or the repayment period.

(e) A public utility shall be permitted to recover the uncollectible costs it incurs in complying with the requirements of this Section, including through the utility's automatic adjustment clause tariff authorized under either Section 16-111.8 or Section 19-145 of this Act. In the event that a public utility does not have such a tariff in effect, then the public utility shall recover such costs consistent with the rules established by the Illinois Commerce Commission pursuant to subparagraph (3) of subsection (f) of this Section.

(f) The Illinois Commerce Commission shall initiate a rulemaking proceeding to establish rules regarding, at a minimum:

(1) what documents or proof the service member must provide to the public utility to establish that the residential premises was the primary residence of the service member immediately before the service member entered military service;

(2) what constitutes "hardship to the consumer" as that term is used in subsection (d) of this Section; and

(3) the mechanism or mechanisms pursuant to which a public utility that does not have in effect an automatic adjustment clause tariff under either Section 16-111.8 or Section 19-145 of this Act shall recover the uncollectible costs it incurs in complying with the requirements of this Section.

(g) In order to be eligible for the benefits granted to a service member under this Section, a service member who receives utility services from a not-for-profit cooperative must provide the cooperative with documentation that his or her military service materially affects his or her ability to pay for the services when payment is due.

(h) A violation of this Section constitutes a civil rights violation under the Illinois Human Rights Act.

All proceeds from the collection of any civil penalty imposed under this subsection shall be deposited into the Illinois Military Family Relief Fund.

(Source: P.A. 97-913, eff. 1-1-13.)

(220 ILCS 5/8-201.6)

Sec. 8-201.6. Deferral of deposit; victims of domestic violence. For the purposes of this Section, "domestic violence" means abuse by a family or household member, as "abuse" and "family or household members" are defined in Section 103 of the Illinois Domestic Violence Act of 1986.

A utility shall defer the utility's initial credit and deposit requirements for a period of 60 days for a residential customer or applicant who is a victim of domestic violence. To be eligible for the deferral under this Section, the domestic violence must (1) have been the basis for the issuance of an order of protection or (2) be certified by treating medical personnel, law enforcement personnel, a State's Attorney, the Attorney General, or a domestic violence shelter. The certification letter must be printed on the certifying entity's letterhead or accompanied by a letter on the certifying entity's letterhead that identifies the certifying individual.

(Source: P.A. 99-420, eff. 1-1-16.)

(220 ILCS 5/8-201.7)

Sec. 8-201.7. Prohibition on deposits for low-income residential customers or applicants.

(a) On and after the effective date of this amendatory Act of the 102nd General Assembly, no electric or gas utility shall, as a condition for standard service, require a low-income residential customer or applicant to provide a deposit as security against potential non-payment for service except when the utility has proof that the customer engaged in tampering of the electric or gas utility equipment during the previous 5 years. Within 60 days after the effective date of this amendatory Act of the 102nd General Assembly, such utility shall refund all deposits collected from low-income customers as security against potential nonpayment for standard service to such residential customers except when the utility has proof that the customer benefited from tampering. Proof that the customer for whom the deposit is being required engaged in tampering shall be the burden of the utility and the utility shall provide the customer the opportunity to contest the finding that the customer engaged in tampering.

(b) As used in this Section:

"Low-income residential customer or applicant" means: (i) a member of a household at or below 80% of the latest median household income as reported by the United States Census Bureau for the most applicable community or county; (ii) a member of a household at or below 150% of the federal poverty level; (iii) a person who is eligible for the Illinois Low Income Home Energy Assistance Program (LIHEAP) as defined in the Energy Assistance Act; (iv) a person who is eligible to participate in the Percentage of Income Payment Plan (PIPP or PIP Plan) as defined in the Energy Assistance Act; or (v) a person who is eligible to receive Lifeline service as defined in the Universal Service Telephone Service Protection Law of 1985.

"Tampering" means any unauthorized alteration of electric or gas utility equipment or facilities by which a benefit is achieved for which the utility is not compensated, including customer self-restoration of utility service.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/8-201.8)

Sec. 8-201.8. Prohibition on late payment fees for low-income residential customers or applicants.

(a) Notwithstanding any other provision of this Act, as of the effective date of this amendatory Act of the 102nd General Assembly, an electric utility shall not charge a low-income residential customer or applicant a fee, charge, or penalty for late payment of any utility bill or invoice. Notwithstanding any other provision of this Act, as of January 1, 2023, a natural gas utility shall not charge a low-income residential customer or applicant a fee, charge, or penalty for late payment of any utility bill or invoice.

(b) As used in this Section, "low-income residential customer or applicant" means: (i) a member of a household at or below 80% of the latest median household income as reported by the United States Census Bureau for the most applicable community or county; (ii) a member of a household at or below 150% of the federal poverty level; (iii) a person who is eligible for the Illinois Low Income Home Energy Assistance Program (LIHEAP) as defined in the Energy Assistance Act; (iv) a person who is eligible to participate in the Percentage of Income Payment Plan (PIPP or PIP Plan) as defined in the Energy Assistance Act; or (v) a person who is eligible to receive Lifeline service as defined in the Universal Service Telephone Service Protection Law of 1985.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/8-201.9)

Sec. 8-201.9. Prohibition on credit card convenience fees.

(a) No electric or natural gas utility shall assess any convenience fee, surcharge, or other fee to any customer who elects to pay for service using a credit card that the electric or natural gas utility would not assess to the customer if the customer paid by other available methods acceptable to the utility. The Commission may consider as an operating expense, for the purpose of determining whether a rate or other charge or classification is sufficient, costs incurred by a utility to process payments described in this Section so long as those costs are determined to be prudent, just, and reasonable.

(b) As used in this Section, "credit card" means an instrument or device, whether known as a credit card, bank card, charge card, debit card, automated teller machine card, secured credit card, smart card, electronic purse, prepaid card, affinity card, or by any other name, issued with or without fee by an issuer for the use of the holder to obtain credit, money, goods, services, or anything else of value.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/8-201.10)

Sec. 8-201.10. Disconnection and credit and collections reporting.

(a) The Commission shall require all gas, electric, water and sewer public utilities under its authority to submit an annual report by May 1, 2022 and every May 1 thereafter, reporting and making publicly available in executable, electronic spreadsheet format, by zip code, on the number of disconnections for nonpayment and reconnections that occurred in the immediately preceding calendar year, as identified in subsection (b).

(b) Each such public utility shall report to the Commission by the 15th day of each month and make publicly available in executable, electronic spreadsheet format the following information, by zip code, for the immediately preceding month:

(1) the number of customers, by customer class and type of utility service provided, during each month;

(2) the number of customers, by customer class and type of utility service, receiving disconnection notices during each month;

(3) the number of customers, by customer class and type of utility service, disconnected for nonpayment during each month;

(4) the number of customers, by customer class and type of utility service, reconnected because they have paid in full or set up payment arrangements during each month;

(5) the number of new deferred payment agreements, by customer class and type of utility service, each month;

(6) the number of customers, by customer class and type of utility service, taking service at the beginning of the month under existing deferred payment arrangements;

(7) the number of customers, by customer class and type of utility service, completing deferred payment arrangements during the month;

(8) the number of payment agreements, by customer class and type of utility service, that failed during each month;

(9) the number of customers, by customer class and type of utility service, renegotiating deferred payment arrangements during the month;

(10) the number of customers, by customer class and type of utility service, assessed late payment fees or charges during the month;

(11) the number of customers, by customer class and type of utility service, taking service at the beginning of the month under existing medical payment arrangements;

(12) the number of customers, by utility service, completing medical payment arrangements during the month;

(13) the number of customers, by utility service, enrolling in new medical payment arrangements during the month;

(14) the number of customers, by utility service, renegotiating medical payment arrangements plans during the month;

(15) the number of customers, by customer class and utility service, with required deposits with the company at the beginning of the month;

(16) the number of customers, by customer class and utility service, required to submit new deposits or increased deposits during the month;

(17) the number of customers, by customer class and utility service, whose required deposits were reduced in part or forgone during the month;

(18) the number of customers, by customer class and utility service, whose deposits were returned in full during the month;

(19) the number of customers, by customer class and utility service, with past due amounts greater than 30 days past due at the beginning of the month and taking service at the beginning of the month under existing deferred payment arrangements;

(20) the dollar volume of past due accounts, by customer class and utility service, for customers with past due amounts greater than 30 days past due at the beginning of the month and taking service at the beginning of the month under existing deferred payment arrangements;

(21) the number of customers, by customer class and utility service, with past due amounts greater than 30 days past due at the beginning of the month and not taking service at the beginning of the month under existing deferred payment arrangements; and

(22) the dollar volume of past due accounts, by customer class and utility service, for customers with past due amounts greater than 30 days past due at the beginning of the month and not taking service at the beginning of the month under existing deferred payment arrangements.

(c) The Commission may specify the executable, electronic spreadsheet format that utilities must adhere to when submitting the information required by this Section. Notwithstanding the requirements of this Section, the Commission may establish an online reporting system and require each public utility to report using the online reporting system instead of filing information in executable, electronic spreadsheet format. The Commission shall make each monthly report submitted by each public utility publicly available on its website within 30 days of receipt.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/8-202) (from Ch. 111 2/3, par. 8-202)

Sec. 8-202. Any public utility, or two or more public utilities, which furnishes electricity or gas for space heating shall, during the calendar months of November, December, January, February, and March:

(a) give written notice of its intention to terminate or cut off such service or supply for any reason, other than by request of the customer, to the customer. Such notice shall be sent by U.S. Mail at least 8 days prior to termination of service or supply or delivered by other means to the customer 5 days prior to such termination; and

(b) deliver written notice of intention to terminate or cut off such service or supply for any reason, other than by request of the customer, to the Director of the local department of public health or, if there is no local department of public health, then to the township supervisor or, if there is no township supervisor, then to the county sheriff where the premises receiving such service or supply is located; and

(c) send, by certified mail, prior written notice of its intention to terminate or cut off such service or supply for any reason, other than by request of the customer, to the owner of record and/or the mortgagee of the premises receiving such service or supply, should the owner of record or mortgagee make request to the public utility for any such notice.

The notice required by paragraphs (b) and (c) of this Section shall be delivered or mailed at least 24 hours and not more than 48 hours prior to the termination of service or supply.

Any termination notice delivered or mailed to a customer shall include a statement advising said customer that the township supervisor, local department of public health, or county sheriff, and the owner and/or the mortgagee, if applicable, will be notified of the termination action at least 24 hours prior to the termination of service or supply.

Nothing in this Act shall be construed to limit the power of the Commission to adopt other rules and regulations pursuant to service termination notices.

No public official to whom notice is given pursuant to subparagraph (b) of this Section shall be liable for death, injury or damages resulting from cut-off of electricity or gas service or supply.

(Source: P.A. 84-617.)

(220 ILCS 5/8-203) (from Ch. 111 2/3, par. 8-203)

Sec. 8-203. No public utility company which furnishes gas or electricity for space heating shall, during the calendar months of October, November, December, January, February and March, terminate or cut off service to any residence or other building at the request of a customer unless:

(a) the customer making the request identifies himself or herself as the owner of the residence or other building or provides reasonable assurance that the owner or the agent thereof has been notified of the request; or

(b) the public utility company has made a reasonable effort to ascertain the owner or the agent thereof and to notify such owner or agent of the request; or

(c) more than 24 hours has elapsed from the time the request was received by the public utility company.

(Source: P.A. 84-617.)

(220 ILCS 5/8-204) (from Ch. 111 2/3, par. 8-204)

Sec. 8-204. Every public utility company which furnishes electricity to residential customers shall (a) maintain a registry of those individuals who are dependent on an electrically operated respirator, dialysis machine or any other electrically operated life-support equipment, and (b) identify with a special tag each meter used in conjunction with the provision of electric service to such individuals. The existence of the registry shall be reasonably publicized by the public utility to its residential customers and the general public. It shall be the responsibility, however, of any individual relying on any life-support equipment to notify the public utility providing electrical service of his or her dependency on such life-support equipment.

(Source: P.A. 86-1424.)

(220 ILCS 5/8-205) (from Ch. 111 2/3, par. 8-205)

Sec. 8-205. (a) Termination of gas and electric utility service to all residential users, including all tenants of mastermetered apartment buildings, for nonpayment of bills, where gas or electricity is used as the only source of space heating or to control or operate the only space heating equipment at the residence is prohibited:

(1) on any day when the National Weather Service forecast for the following 24 hours covering the area of the utility in which the residence is located includes a forecast that the temperature will be 32 degrees Fahrenheit or below; or

(2) on any day preceding a holiday or a weekend when such a forecast indicated that the temperature will be 32 degrees Fahrenheit or below during the holiday or weekend.

(b) If gas or electricity is used as the only source of space cooling or to control or operate the only space cooling equipment at a residence, then a utility may not terminate gas or electric utility service to a residential user, including all tenants of mastermetered apartment buildings, for nonpayment of bills:

(1) on any day when the National Weather Service forecast for the following 24 hours covering the area of the utility in which the residence is located includes a forecast that the temperature will be 90 degrees Fahrenheit or above;

(2) on any day preceding a holiday or weekend when the National Weather Service for the following 24 hours covering the area of the utility in which the residence is located includes a forecast that the temperature will be 90 degrees Fahrenheit or above during the holiday or weekend; or

(3) when the National Weather Service issues an excessive heat watch, heat advisory, or excessive heat warning covering the area of the utility in which the residence is located.

(Source: P.A. 103-19, eff. 1-1-24; 103-605, eff. 7-1-24.)

(220 ILCS 5/8-206) (from Ch. 111 2/3, par. 8-206)

Sec. 8-206. Winter termination for nonpayment.

(a) Notwithstanding any other provision of this Act, no electric or gas public utility shall disconnect service to any residential customer or mastermetered apartment building for nonpayment of a bill or deposit where gas or electricity is used as the primary source of space heating or is used to control or operate the primary source of space heating equipment at the premises during the period of time from December 1 through and including March 31 of the immediately succeeding calendar year, unless:

(1) The utility (i) has offered the customer a deferred payment arrangement allowing for payment of past due amounts over a period of not less than 4 months not to extend beyond the following November and the option to enter into a levelized payment plan for the payment of future bills. The maximum down payment requirements shall not exceed 10% of the amount past due and owing at the time of entering into the agreement; and (ii) has provided the customer with the names, addresses and telephone numbers of governmental and private agencies which may provide assistance to customers of public utilities in paying their utility bills; the utility shall obtain the approval of an agency before placing the name of that agency on any list which will be used to provide such information to customers;

(2) The customer has refused or failed to enter into a deferred payment arrangement as described in paragraph (1) of this subsection (a); and

(3) All notice requirements as provided by law and rules or regulations of the Commission have been met.

(b) Prior to termination of service for any residential customer or mastermetered apartment building during the period from December 1 through and including March 31 of the immediately succeeding calendar year, all electric and gas public utilities shall, in addition to all other notices:

(1) Notify the customer or an adult residing at the customer's premises by telephone, a personal visit to the customer's premises or by first class mail, informing the customer that:

(i) the customer's account is in arrears and the customer's service is subject to termination for nonpayment of a bill;

(ii) the customer can avoid disconnection of service by entering into a deferred payment agreement to pay past due amounts over a period not to extend beyond the following November and the customer has the option to enter into a levelized payment plan for the payment of future bills;

(iii) the customer may apply for any available assistance to aid in the payment of utility bills from any governmental or private agencies from the list of such agencies provided to the customer by the utility.

Provided, however, that a public utility shall be required to make only one such contact with the customer during any such period from December 1 through and including March 31 of the immediately succeeding calendar year.

(2) Each public utility shall maintain records which shall include, but not necessarily be limited to, the manner by which the customer was notified and the time, date and manner by which any prior but unsuccessful attempts to contact were made. These records shall also describe the terms of the deferred payment arrangements offered to the customer and those entered into by the utility and customers. These records shall indicate the total amount past due, the down payment, the amount remaining to be paid and the number of months allowed to pay the outstanding balance. No public utility shall be required to retain records pertaining to unsuccessful attempts to contact or deferred payment arrangements rejected by the customer after such customer has entered into a deferred payment arrangement with such utility.

(c) No public utility shall disconnect service for nonpayment of a bill until the lapse of 6 business days after making the notification required by paragraph (1) of subsection (b) so as to allow the customer an opportunity to:

(1) Enter into a deferred payment arrangement and the option to enter into a levelized payment plan for the payment of future bills.

(2) Contact a governmental or private agency that may provide assistance to customers for the payment of public utility bills.

(d) Any residential customer who enters into a deferred payment arrangement pursuant to this Act, and subsequently during that period of time set forth in subsection (a) becomes subject to termination, shall be given notice as required by law and any rule or regulation of the Commission prior to termination of service.

(e) During that time period set forth in subsection (a), a utility shall not require a down payment for a deposit from a residential customer in excess of 20% of the total deposit requested. An additional 4 months shall be allowed to pay the remainder of the deposit. This provision shall not apply to mastermetered apartment buildings or other nonresidential customers.

(f) During that period of time set forth in subsection (a), no utility may refuse to offer a deferred payment agreement to a residential customer who has defaulted on such an agreement within the past 12 months. However, no utility shall be required to enter into more than one deferred payment arrangement under this Section with any residential customer or mastermetered apartment building during the period from December 1 through and including March 31 of the immediately succeeding calendar year.

(g) In order to enable customers to take advantage of energy assistance programs, customers who can demonstrate that their applications for a local, state or federal energy assistance program have been approved may request that the amount they will be entitled to receive as a regular energy assistance payment be deducted and set aside from the amount past due on which they make deferred payment arrangements. Payment on the set-aside amount shall be credited when the energy assistance voucher or check is received, according to the utility's common business practice.

(h) In no event shall any utility send a final notice to any customer who has entered into a current deferred payment agreement and has not defaulted on that deferred payment agreement, unless the final notice pertains to a deposit request.

(i) Each utility shall include with each disconnection notice sent during the period for December 1 through and including March 31 of the immediately succeeding calendar year to a residential customer an insert explaining the above provisions and providing a telephone number of the utility company which the consumer may call to receive further information.

(j) Each utility shall file with the Commission prior to December 1 of each year a plan detailing the implementation of this Section. This plan shall contain, but not be limited to:

(1) a description of the methods to be used to notify residential customers as required in this Section, including the forms of written and oral notices which shall be required to include all the information contained in subsection (b) of this Section.

(2) a listing of the names, addresses and telephone numbers of governmental and private agencies which may provide assistance to residential customers in paying their utility bills.

(3) the program of employee education and information which shall be used by the company in the implementation of this Section.

(4) a description of methods to be utilized to inform residential customers of those governmental and private agencies and current and planned methods of cooperation with those agencies to identify the customers who qualify for assistance in paying their utility bills.

A utility which has a plan on file with the Commission need not resubmit a new plan each year. However, any alteration of the plan on file must be submitted and approved prior to December 1 of any year.

All plans are subject to review and approval by the Commission. The Commission may direct a utility to alter its plan to comply with the requirements of this Section.

(k) Notwithstanding any other provision of this Act, no electric or gas public utility shall disconnect service to any residential customer who is a participant under Section 6 of the Energy Assistance Act for nonpayment of a bill or deposit where gas or electricity is used as the primary source of space heating or is used to control or operate the primary source of space heating equipment at the premises during the period of time from December 1 through and including March 31 of the immediately succeeding calendar year.

(l) Notwithstanding any other provision of this Act, no electric or gas public utility shall disconnect service to any residential customer who has notified the utility that he or she is a service member or veteran for nonpayment of a bill or deposit where gas or electricity is used as the primary source of space heating or is used to control or operate the primary source of space heating equipment at the premises during the period of time from December 1 through and including March 31 of the immediately succeeding calendar year.

(Source: P.A. 97-77, eff. 1-1-12.)

(220 ILCS 5/8-206.5)

(This Section may contain text from a Public Act with a delayed effective date)

Sec. 8-206.5. Disconnection Protection Program.

(a) No later than June 1, 2025, each electric and gas utility serving more than 500,000 customers in this State shall implement a Disconnection Protection Program, whereby customers who have applied for assistance through the Low Income Home Energy Assistance Program (LIHEAP) or Percentage of Income Payment Plan (PIPP) shall be temporarily protected from disconnection for 30 days after the utility receives notice from a local administrative agency that the customer has submitted an application to LIHEAP or PIPP and, in cases where LIHEAP or PIPP assistance is received, for another 45 days after receiving the notice. Any customer who applies for, but does not receive, LIHEAP or PIPP assistance shall, by operation of this Section, only be temporarily protected from disconnection once in any program year.

(b) Each electric and gas utility may recover costs for implementation, administration, and ongoing operation of its Disconnection Protection Program through the utility's revenue requirement, subject to a review for prudence and reasonableness by the Commission.

(Source: P.A. 103-661, eff. 1-1-25.)

(220 ILCS 5/8-207) (from Ch. 111 2/3, par. 8-207)

Sec. 8-207. Any former residential customer whose gas or electric service was used to provide or control the primary source of space heating in the dwelling and whose service is disconnected for nonpayment of a bill or a deposit from December 1 of the prior winter's heating season through April 1 of the current heating season shall be eligible for reconnection and a deferred payment arrangement under the provisions of this Section, subject to the following limitations:

A utility shall not be required to reconnect service to, and enter into a deferred payment arrangement with, a former customer under the provisions of this Section (1) except between November 1 and April 1 of the current heating season for former customers who do not have applications pending for the program described in Section 6 of the Energy Assistance Act, and except between October 1 and April 1 of the current heating season for all former customers who do have applications pending for the program described in Section 6 of the Energy Assistance Act and who provide proof of application to the utility, (2) in 2 consecutive years, (3) unless that former customer has paid at least 33 1/3% of the amount billed for utility service rendered by that utility subsequent to December 1 of the prior year, or (4) in any instance where the utility can show there has been tampering with the utility's wires, pipes, meters (including locking devices), or other service equipment and further shows that the former customer enjoyed the benefit of utility service obtained in the aforesaid manner.

The terms and conditions of any deferred payment arrangements established by the utility and a former customer shall take into consideration the following factors, based upon information available from current utility records or provided by the former customer:

(1) the amount past due;

(2) the former customer's ability to pay;

(3) the former customer's payment history;

(4) the reasons for the accumulation of the past due amounts; and

(5) any other relevant factors relating to the former customer's circumstances.

After the former customer's eligibility has been established in accordance with the first paragraph of this Section and, upon the establishment of a deferred payment agreement, the former customer shall pay 1/3 of the amount past due (including reconnecting charge, if any) and 1/3 of any deposit required by the utility.

Upon the payment of 1/3 of the amount past due and 1/3 of any deposit required by the utility, the former customer's service shall be reconnected as soon as possible. The company and the former customer shall agree to a payment schedule for the remaining balances which will reasonably allow the former customer to make the payments on the remainder of the deposit and the past due balance while paying current bills during the winter heating season. However, the utility is not obliged to make payment arrangements extending beyond the following November. The utility shall allow the former customer a minimum of 4 months in which to retire the past due balance and 3 months in which to pay the remainder of the deposit. The former customer shall also be informed that payment on the amounts past due and the deposit, if any, plus the current bills must be paid by the due date or the customer may face termination of service pursuant to this Section and Section 8-206.

The Commission shall develop rules to govern the reconnection of a former customer who demonstrates a financial inability to meet the requirement of 1/3 of the amount past due and 1/3 of any deposit requested by the utility. The Commission's rules shall establish a means by which the former customer's utility service may be reconnected through the payment of a reasonable amount and upon entering into a deferred payment agreement.

Any payment agreement made shall be in writing, with a copy provided to the former customer. The renegotiation and reinstatement of a customer and the establishment of a budget payment plan shall be pursuant to rules established by the Commission.

Not later than September 15 of each year, every gas and electric utility shall conduct a survey of all former residential customers whose gas or electric service was used to provide or control the primary source of space heating in the dwelling and whose gas or electric service was terminated for nonpayment of a bill or deposit from December 1 of the previous year to September 15 of that year and where service at that premises has not been restored. Not later than October 1 of each year the utility shall notify each of these former customers that the gas or electric service will be restored by the company for the coming heating season if the former customer contacts the utility and makes arrangements with the utility for reconnection of service under the conditions set forth in this Section. A utility shall notify the former customer or an adult member of the household by personal visit, telephone contact or mailing of a letter by first class mail to the last known address of that former customer. The utility shall keep records which would indicate the date, form and the results of such contact.

Each gas and electric utility which has former customers affected by this Section shall file reports with the Commission providing such information as the Commission may deem appropriate. The Commission shall notify each gas and electric utility prior to August 1 of each year concerning the information which is to be included in the report for that year.

In no event shall any actions taken by a utility in compliance with this Section be deemed to abrogate or in any way interfere with the utility's rights to pursue the normal collection processes otherwise available to it.

The Commission shall promulgate rules to implement this Section.

(Source: P.A. 92-690, eff. 7-18-02.)

(220 ILCS 5/8-208)

Sec. 8-208. (a) The General Assembly finds that the availability of adequate, affordable housing bears a close relationship to efficient and reliable delivery of utility services and that the lack of affordable housing exacerbates difficulties in the delivery of electric services. It is further found that the meeting of electric public utility service obligations imposed under this Act can be attained by allocating certain resources to alleviating housing needs. It is declared to be the public policy of this State that prudent investments in or contributions to projects that foster the availability of adequate, affordable housing furthers the goals and objectives of this Act.

(b) Beginning in calendar year 1994 and continuing through calendar year 2014, a public utility providing electric service to more than 1,000,000 customers in this State shall contribute, from retained earnings, each year $500,000 to the Illinois Affordable Housing Trust Fund created by the Illinois Affordable Housing Act.

(Source: P.A. 88-83; 88-653, eff. 1-1-95.)

(220 ILCS 5/8-209)

Sec. 8-209. Utility credit reporting. If a public utility reports a customer to a credit reporting agency for non-payment of an outstanding utility bill, then a public utility shall notify the credit reporting agency within 5 business days of any full payment made with certified funds or cash. For the purposes of this amendatory Act of the 97th General Assembly, certified funds means instruments that are guaranteed by the issuing institution or have cleared the issuing institution.

(Source: P.A. 97-821, eff. 1-1-13.)

(220 ILCS 5/8-218)

Sec. 8-218. Utility-scale pilot projects.

(a) Electric utilities serving greater than 500,000 customers but less than 3,000,000 customers may propose, plan for, construct, install, control, own, manage, or operate up to 2 pilot projects consisting of utility-scale photovoltaic energy generation facilities. A pilot project may consist of photovoltaic energy generation facilities located on one or more sites and may be installed or constructed in phases. Energy storage facilities that are planned for, constructed, installed, controlled, owned, managed, or operated may be constructed in connection with the photovoltaic electricity generation pilot projects.

(b) Pilot projects shall be sited in equity investment eligible communities in or near the towns of Peoria and East St. Louis and must result in economic benefits for the members of the communities in which the project will be located. The amount paid per pilot project with or without energy storage facilities cannot exceed $20,000,000. The electric utility's costs of planning for, constructing, installing, controlling, owning, managing, or operating the photovoltaic electricity generation facilities and energy storage facilities may be recovered, on a kilowatt hour basis, via an automatic adjustment clause tariff applicable to all retail customers, with the tariff to be approved by the Commission after opportunity for review, and with an annual reconciliation component; and for purposes of cost recovery, the photovoltaic electricity production facilities may be treated as regulatory assets, using the same ratemaking treatment in paragraph (1) of subsection (h) of Section 16-107.6 of this Act, provided: (1) the Commission shall have the authority to determine the reasonableness of the costs of the facilities, and (2) any monetary value of power and energy from the facilities shall be credited against the delivery services revenue requirement.

(c) Any electric utility seeking to propose, plan for, construct, install, control, own, manage, or operate a pilot project pursuant to this Section must commit to using a diverse and equitable workforce and a diverse set of contractors, including minority-owned businesses, disadvantaged businesses, trade unions, graduates of any workforce training programs established by this amendatory Act of the 102nd General Assembly, and small businesses. An electric utility must comply with the equity commitment requirements in subsection (c-10) of Section 1-75 of the Illinois Power Agency Act. The electric utility must certify that not less than the prevailing wage will be paid to employees engaged in construction activities associated with the pilot project. The electric utility must file a project labor agreement, as defined in the Illinois Power Agency Act, with the Commission prior to constructing, installing, controlling, or owning a pilot project authorized by this Section.

(Source: P.A. 102-662, eff. 9-15-21; 102-1031, eff. 5-27-22.)

(220 ILCS 5/8-301) (from Ch. 111 2/3, par. 8-301)

Sec. 8-301. The Commission shall have power to ascertain, determine and fix for each kind of public utility suitable and convenient standard commercial units of service, product or commodity, which units shall be lawful units for the purposes of this Act; to ascertain, determine and fix adequate and serviceable standards for the measurements of quantity, quality, pressure, initial voltage or other condition pertaining to the performing of its service or to the furnishing of its product or commodity by any public utility, and to prescribe reasonable regulations for examining, measuring and testing such service, product or commodity, and to establish reasonable rules, regulations, specifications and standards to secure the accuracy of all meters and appliances for examining, measuring or testing such service, product or commodity. The Commission may purchase such materials, apparatus and standard measuring instruments as it deems necessary to carry out the provisions of this Section.

The Commission shall provide for the inspection of the manner in which every public utility conforms to the reasonable regulations prescribed by the Commission for examining, measuring and testing its service, product or commodity, and the Commission may supplement such inspections by examining, measuring and testing the service, product or commodity of any public utility. Any consumer or user may have tested any appliance for examining, measuring or testing any such service, product or commodity upon payment of the fees fixed by the Commission. The Commission shall declare and establish reasonable fees to be paid for examining and testing such appliances on the request of consumers or users, the fee to be paid by the consumer or user at the time of his request, but to be repaid to the consumer or user by the public utility if the measuring appliance be found unreasonably defective or incorrect to the disadvantage of the consumer or user.

The Commission, its officers, agents, experts or inspectors and employees shall have power to enter upon any premises occupied by any public utility for the purpose of making the examinations and tests provided in the Act, and set up and use on such premises, any apparatus and appliances and occupy reasonable space therefor.

All fees collected by the Commission under this Section shall be paid promptly after the receipt of the same, accompanied by a detailed statement of the same, into the Public Utility Fund in the State treasury.

(Source: P.A. 84-617.)

(220 ILCS 5/8-302) (from Ch. 111 2/3, par. 8-302)

Sec. 8-302. The Commission shall require that every public utility furnishing natural or artificial gas, electricity or water to the public, where the individual consumption is measured by meter, shall, upon written request of any consumer, cause the meter reader at the time of reading such consumer's meter to leave at such meter a card showing the present reading of the meter, the last previous reading, and the dates of such two readings.

(Source: P.A. 84-617.)

(220 ILCS 5/8-303) (from Ch. 111 2/3, par. 8-303)

Sec. 8-303. Where, within 30 days of receipt of a utility bill, a customer alleges that the level of consumption reflected in his utility bill is unreasonably high, it shall be the responsibility of the public utility furnishing natural or artificial gas, electricity or water to that customer to investigate the allegation. If as a result of such an investigation, the public utility determines that the customer's line has been tapped, the utility shall attempt to ascertain the identity of the third party benefiting from the usage of the utility service or for payment for all or part of the disputed charges. If the utility determines that the landlord of the building or his agent is the party who benefited from the usage of the utility service, either the utility or the customer may petition the court for the appointment of receiver to collect the rents due and to remit a portion to the utility company for payment of bills for the tapped service, for current bills and for any expenses incurred by the utility as a result of the tap. The receiver shall make all reasonable efforts, including the obtaining of court orders, to provide to the utility access to the building. Any changes in the building's piping which are necessitated by the tap shall be at the expense of the person benefiting from the tap.

If the utility determines that the landlord of the building is not the party who benefited from the usage of the utility service, the customer shall be so notified and shall also be informed by the utility of a right to register a dispute pursuant to procedures developed by the Commission for resolution of disputed bills, including his right to bring a complaint before the Commission if an agreement with the utility cannot be reached.

In order to enable the customer to ascertain whether the level of consumption is greater than the amounts billed in other billing periods and to eliminate to the fullest extent practicable consecutive estimated bills, the public utility shall make an actual meter reading at least every second billing period. If a meter reader is unable to gain access to the meter for the purpose of making an actual reading, the public utility shall take other appropriate and reasonable measures to read the meter.

Nothing in this Section shall preclude either the customer or the public utility from filing a complaint with the State's Attorney located in the county where the utility service is being rendered to allege an unlawful theft of the customer's utility service.

(Source: P.A. 84-617.)

(220 ILCS 5/8-304)

Sec. 8-304. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/8-305)

Sec. 8-305. Braille billing statements. Upon the request of a customer, a public utility that serves at least 50,000 customers shall furnish billing statements in braille.

(Source: P.A. 88-497.)

(220 ILCS 5/8-306)

Sec. 8-306. Special provisions relating to water and sewer utilities.

(a) No later than 120 days after the effective date of this amendatory Act of the 94th General Assembly, the Commission shall prepare, make available to customers upon request, and post on its Internet web site information concerning the service obligations of water and sewer utilities and remedies that a customer may pursue for a violation of the customer's rights. The information shall specifically address the rights of a customer of a water or sewer utility in the following situations:

(1) The customer's water meter is replaced.

(2) The customer's bill increases by more than 50% within one billing period.

(3) The customer's water service is terminated.

(4) The customer wishes to complain after receiving a termination of service notice.

(5) The customer is unable to make payment on a billing statement.

(6) A rate is filed, including without limitation a surcharge or annual reconciliation filing, that will increase the amount billed to the customer.

(7) The customer is billed for services provided prior to the date covered by the billing statement.

(8) The customer is due to receive a credit.

Each billing statement issued by a water or sewer utility shall include an Internet web site address where the customer can view the information required under this subsection (a) and a telephone number that the customer may call to request a copy of the information.

(b) A water or sewer utility may discontinue service only after it has mailed or delivered by other means a written notice of discontinuance substantially in the form of Appendix A of 83 Ill. Adm. Code 280. The notice must include the Internet web site address where the customer can view the information required under subsection (a) and a telephone number that the customer may call to request a copy of the information. Any notice required to be delivered or mailed to a customer prior to discontinuance of service shall be delivered or mailed separately from any bill. Service shall not be discontinued until at least 5 days after delivery or 8 days after the mailing of this notice. Service shall not be discontinued and shall be restored if discontinued for the reason which is the subject of a dispute or complaint during the pendency of informal or formal complaint procedures of the Illinois Commerce Commission under 83 Ill. Adm. Code 280.160 or 280.170, where the customer has complied with those rules. Service shall not be discontinued and shall be restored if discontinued where a customer has established a deferred payment agreement pursuant to 83 Ill. Adm. Code 280.110 and has not defaulted on such agreement. Residential customers who are indebted to a utility for past due utility service shall have the opportunity to make arrangements with the utility to retire the debt by periodic payments, referred to as a deferred payment agreement, unless this customer has failed to make payment under such a plan during the past 12 months. The terms and conditions of a reasonable deferred payment agreement shall be determined by the utility after consideration of the following factors, based upon information available from current utility records or provided by the customer or applicant:

(1) size of the past due account;

(2) customer or applicant's ability to pay;

(3) customer or applicant's payment history;

(4) reason for the outstanding indebtedness; and

(5) any other relevant factors relating to the circumstances of the customer or applicant's service.

A residential customer shall pay a maximum of one-fourth of the amount past due and owing at the time of entering into the deferred payment agreement, and the water or sewer utility shall allow a minimum of 2 months from the date of the agreement and a maximum of 12 months for payment to be made under a deferred payment agreement. Late payment charges may be assessed against the amount owing that is the subject of a deferred payment agreement.

(c) A water or sewer utility shall provide notice as required by subsection (a) of Section 9-201 after the filing of each information sheet under a purchased water surcharge, purchased sewage treatment surcharge, or qualifying infrastructure plant surcharge. The utility also shall post notice of the filing in accordance with the requirements of 83 Ill. Adm. Code 255. Unless filed as part of a general rate increase, notice of the filing of a purchased water surcharge rider, purchased sewage treatment surcharge rider, or qualifying infrastructure plant surcharge rider also shall be given in the manner required by this subsection (c) for the filing of information sheets.

(d) Commission rules pertaining to formal and informal complaints against public utilities shall apply with full and equal force to water and sewer utilities and their customers, including provisions of 83 Ill. Adm. Code 280.170, and the Commission shall respond to each complaint by providing the consumer with a copy of the utility's response to the complaint and a copy of the Commission's review of the complaint and its findings. The Commission shall also provide the consumer with all available options for recourse.

(e) Any refund shown on the billing statement of a customer of a water or sewer utility must be itemized and must state if the refund is an adjustment or credit.

(f) Water service for building construction purposes. At the request of any municipality or township within the service area of a public utility that provides water service to customers within the municipality or township, a public utility must (1) require all water service used for building construction purposes to be measured by meter and subject to approved rates and charges for metered water service and (2) prohibit the unauthorized use of water taken from hydrants or service lines installed at construction sites.

(g) Water meters.

(1) Periodic testing. Unless otherwise approved by the Commission, each service water meter shall be periodically inspected and tested in accordance with the schedule specified in 83 Ill. Adm. Code 600.340, or more frequently as the results may warrant, to insure that the meter accuracy is maintained within the limits set out in 83 Ill. Adm. Code 600.310.

(2) Meter tests requested by customer.

(A) Each utility furnishing metered water service shall, without charge, test the accuracy of any meter upon request by the customer served by such meter, provided that the meter in question has not been tested by the utility or by the Commission within 2 years previous to such request. The customer or his or her representatives shall have the privilege of witnessing the test at the option of the customer. A written report, giving the results of the test, shall be made to the customer.

(B) When a meter that has been in service less than 2 years since its last test is found to be accurate within the limits specified in 83 Ill. Adm. Code 600.310, the customer shall pay a fee to the utility not to exceed the amounts specified in 83 Ill. Adm. Code 600.350(b). Fees for testing meters not included in this Section or so located that the cost will be out of proportion to the fee specified will be determined by the Commission upon receipt of a complete description of the case.

(3) Commission referee tests. Upon written application to the Commission by any customer, a test will be made of the customer's meter by a representative of the Commission. For such a test, a fee as provided for in subsection (g)(2) shall accompany the application. If the meter is found to be registering more than 1.5% fast on the average when tested as prescribed in 83 Ill. Adm. Code 600.310, the utility shall refund to the customer the amount of the fee. The utility shall in no way disturb the meter after a customer has made an application for a referee test until authority to do so is given by the Commission or the customer in writing.

(h) Water and sewer utilities; low usage. Each public utility that provides water and sewer service must establish a unit sewer rate, subject to review by the Commission, that applies only to those customers who use less than 1,000 gallons of water in any billing period.

(i) Water and sewer utilities; separate meters. Each public utility that provides water and sewer service must offer separate rates for water and sewer service to any commercial or residential customer who uses separate meters to measure each of those services. In order for the separate rate to apply, a combination of meters must be used to measure the amount of water that reaches the sewer system and the amount of water that does not reach the sewer system.

(j) Each water or sewer public utility must disclose on each billing statement any amount billed that is for service provided prior to the date covered by the billing statement. The disclosure must include the dates for which the prior service is being billed. Each billing statement that includes an amount billed for service provided prior to the date covered by the billing statement must disclose the dates for which that amount is billed and must include a copy of the document created under subsection (a) and a statement of current Commission rules concerning unbilled or misbilled service.

(k) When the customer is due a refund resulting from payment of an overcharge, the utility shall credit the customer in the amount of overpayment with interest from the date of overpayment by the customer. The rate for interest shall be at the appropriate rate determined by the Commission under 83 Ill. Adm. Code 280.70.

(l) Water and sewer public utilities; subcontractors. The Commission shall adopt rules for water and sewer public utilities to provide notice to the customers of the proper kind of identification that a subcontractor must present to the customer, to prohibit a subcontractor from soliciting or receiving payment of any kind for any service provided by the water or sewer public utility or the subcontractor, and to establish sanctions for violations.

(m) Water and sewer public utilities; unaccounted-for water. By December 31, 2006, each water public utility shall file tariffs with the Commission to establish the maximum percentage of unaccounted-for water that would be considered in the determination of any rates or surcharges. The rates or surcharges approved for a water public utility shall not include charges for unaccounted-for water in excess of this maximum percentage without well-documented support and justification for the Commission to consider in any request to recover charges in excess of the tariffed maximum percentage.

(n) Rate increases; public forums. When any public utility providing water or sewer service proposes a general rate increase, in addition to other notice requirements, the water or sewer public utility must notify its customers of their right to request a public forum. A customer or group of customers must make written request to the Commission for a public forum and must also provide written notification of the request to the customer's municipal or, for unincorporated areas, township government. The Commission, at its discretion, may schedule the public forum. If it is determined that public forums are required for multiple municipalities or townships, the Commission shall schedule these public forums, in locations within approximately 45 minutes drive time of the municipalities or townships for which the public forums have been scheduled. The public utility must provide advance notice of 30 days for each public forum to the governing bodies of those units of local government affected by the increase. The day of each public forum shall be selected so as to encourage the greatest public participation. Each public forum will begin at 7:00 p.m. Reports and comments made during or as a result of each public forum must be made available to the hearing officials and reviewed when drafting a recommended or tentative decision, finding or order pursuant to Section 10-111 of this Act.

(Source: P.A. 94-950, eff. 6-27-06.)

(220 ILCS 5/8-401) (from Ch. 111 2/3, par. 8-401)

Sec. 8-401. Every public utility subject to this Act shall provide service and facilities which are in all respects adequate, efficient, reliable and environmentally safe and which, consistent with these obligations, constitute the least-cost means of meeting the utility's service obligations.

(Source: P.A. 84-617.)

(220 ILCS 5/8-402) (from Ch. 111 2/3, par. 8-402)

Sec. 8-402. (Repealed).

(Source: P.A. 89-445, eff. 2-7-96. Repealed by P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/8-402.1) (from Ch. 111 2/3, par. 8-402.1)

Sec. 8-402.1. (Repealed).

(Source: P.A. 87-173. Repealed by P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/8-402.2)

(Text of Section before amendment by P.A. 103-684)

Sec. 8-402.2. Public Schools Carbon-Free Assessment programs.

(a) Within one year after the effective date of this amendatory Act of the 102nd General Assembly, each electric utility serving over 500,000 retail customers in this State shall implement a Public Schools Carbon-Free Assessment program.

(b) Each utility's Public Schools Carbon-Free Assessment program shall include the following requirements:

(1) Each plan shall be designed to offer within the utility's service territory to assist public schools, as defined by Section 1-3 of the School Code, to increase the efficiency of their energy usage, to reduce the carbon emissions associated with their energy usage, and to move toward a goal of public schools being carbon-free in their energy usage by 2030. The program shall include a target of completing Public Schools Carbon-Free Assessment for all public schools in the utility's service territory by December 31, 2029.

(2) The Public Schools Carbon-Free Assessment shall be a generally standardized assessment, but may incorporate flexibility to reflect the circumstances of individual public schools and public school districts.

(3) The Public Schools Carbon-Free Assessment shall include, but not be limited to, comprehensive analyses of the following subjects:

(A) The top energy efficiency savings opportunities for the public school, by energy saved;

(B) The total achievable solar energy potential on or nearby a public school's premises and able to provide power to a school;

(C) The infrastructure required to support electrification of the facility's space heating and water heating needs;

(D) The infrastructure requirements to support electrification of a school's transportation needs; and

(E) The investments required to achieve a WELL Certification or similar certification as determined through methods developed and updated by the International WELL Building Institute or similar or successor organizations.

(4) The Public Schools Carbon-Free Assessment also shall include, but not be limited to, mechanical insulation evaluation inspection and inspection of the building envelope(s).

(5) With respect to those public school construction projects for public schools within the service territory of a utility serving over 500,000 retail customers in this State and for which a public school district applies for a grant under Section 5-40 of the School Construction Law on or after June 1, 2023, the district must submit a copy of the applicable Public Schools Carbon-Free Assessment report, or, if no such Public Schools Carbon-Free Assessment has been performed, request the applicable utility to perform such a Public Schools Carbon-Free Assessment and submit a copy of the Public Schools Carbon-Free Assessment report promptly when it becomes available. The Public Schools Carbon-Free Assessment report shall include, but not limited to, an energy audit of both the building envelope and the building's mechanical insulation system. It shall also include an inspection of both the building envelope and the mechanical insulation system. The district must demonstrate how the construction project is designed and managed to achieve the goals that all public elementary and secondary school facilities in the State are able to be powered by clean energy by 2030, and for such facilities to achieve carbon-free energy sources for space heat, water heat, and transportation by 2050.

(6) The results of each Public Schools Carbon-Free Assessment shall be memorialized by the utility or by a third party acting on behalf of the utility in a non-confidential report form that includes recommendations and redacts all confidential information and shall be provided to the applicable public school. Each utility shall be required to retain a copy of each Public Schools Carbon-Free Assessment report and to provide copies of each non-confidential report to the Illinois Power Agency and the Illinois Capital Development Board within 3 months of its completion. The Illinois Power Agency shall promptly make the results of each non-confidential report available for public inspection on its website.

(7) The Public Schools Carbon-Free Assessment shall be conducted in coordination with each utility's energy efficiency and demand-response plans under Sections 8-103, 8-103A, and 8-103B of this Act, to the extent applicable. Nothing in this Section is intended to modify or require modification of those plans. However, the utility may request a modification of a plan approved by the Commission, and the Commission may approve the requested modification, if the modification is consistent with the provisions of this Section and Section 8-103B of this Act.

(8) If there are no other providers of assessments that are substantively the same as those being performed by utilities pursuant to this Section by 2024, a utility that has a Public Schools Carbon-Free Assessment program may offer assessments to public schools that are not served by a utility subject to this Section at the utility's cost.

(9) The Public Schools Carbon-Free Assessment shall be offered to and performed for public schools in the utility's service territory on a complimentary basis by each utility, with no Assessment fee charged to the public schools for the Assessments. Nothing in this Section is intended to prohibit the utility from recovering through rates approved by the Commission the utility's prudent and reasonable costs of complying with this Section.

(10) Utilities shall make efforts to prioritize the completion of Public Schools Carbon-Free Assessments for the following school districts by December 31, 2022: East St. Louis School District 189, Harvey School District 152, Thornton Township High School District 205. Utilities shall also prioritize the completion of Public Schools Carbon-Free Assessments for schools located within environmental justice communities or schools that are categorized as a Tier 1 or Tier 2 school based on the latest annual evidence-based funding distribution process by the State Board of Education.

(Source: P.A. 102-662, eff. 9-15-21; 102-1123, eff. 1-27-23.)

(Text of Section after amendment by P.A. 103-684)

Sec. 8-402.2. Public Schools Carbon-Free Assessment programs.

(a) Within one year after the effective date of this amendatory Act of the 102nd General Assembly, each electric utility serving over 500,000 retail customers in this State shall implement a Public Schools Carbon-Free Assessment program.

(b) Each utility's Public Schools Carbon-Free Assessment program shall include the following requirements:

(1) Each plan shall be designed to offer within the utility's service territory to assist public schools, as defined by Section 1-3 of the School Code, to increase the efficiency of their energy usage, to reduce the carbon emissions associated with their energy usage, and to move toward a goal of public schools being carbon-free in their energy usage by 2030. The program shall include a target of completing Public Schools Carbon-Free Assessment for all public schools in the utility's service territory by December 31, 2029.

(2) The Public Schools Carbon-Free Assessment shall be a generally standardized assessment, but may incorporate flexibility to reflect the circumstances of individual public schools and public school districts.

(3) The Public Schools Carbon-Free Assessment shall include, but not be limited to, comprehensive analyses of the following subjects:

(A) The top energy efficiency savings opportunities for the public school, by energy saved;

(B) The total achievable solar energy potential on or nearby a public school's premises and able to provide power to a school;

(C) The infrastructure required to support electrification of the facility's space heating and water heating needs;

(D) The infrastructure requirements to support electrification of a school's transportation needs; and

(E) The investments required to achieve a WELL Certification or similar certification as determined through methods developed and updated by the International WELL Building Institute or similar or successor organizations.

(4) The Public Schools Carbon-Free Assessment also shall include, but not be limited to, mechanical insulation evaluation inspection and inspection of the building envelope(s).

(5) With respect to those public school construction projects for public schools within the service territory of a utility serving over 500,000 retail customers in this State and for which a public school district applies for a grant under Section 5-40 of the School Construction Law on or after June 1, 2023, the district must submit a copy of the applicable Public Schools Carbon-Free Assessment report, or, if no such Public Schools Carbon-Free Assessment has been performed, request the applicable utility to perform such a Public Schools Carbon-Free Assessment and submit a copy of the Public Schools Carbon-Free Assessment report promptly when it becomes available. The Public Schools Carbon-Free Assessment report shall include, but not limited to, an energy audit of both the building envelope and the building's mechanical insulation system. It shall also include an inspection of both the building envelope and the mechanical insulation system. The district must demonstrate how the construction project is designed and managed to achieve the goals that all public elementary and secondary school facilities in the State are able to be powered by clean energy by 2030, and for such facilities to achieve carbon-free energy sources for space heat, water heat, and transportation by 2050.

(6) The results of each Public Schools Carbon-Free Assessment shall be memorialized by the utility or by a third party acting on behalf of the utility in a non-confidential report form that includes recommendations and redacts all confidential information. For purposes of this Section, "confidential information" means information or facts expected and intended to be exempt from disclosure under the Freedom of Information Act. "Confidential information" does not include program offerings, solar opportunities, health and safety certifications, energy efficiency recommendations, information about transportation and other funding offerings. The non-confidential form shall be provided to the applicable public school by the utility or the third party acting on behalf of the utility. Each utility shall be required to retain a copy of each Public Schools Carbon-Free Assessment report and to provide copies of each non-confidential report to the Illinois Power Agency and the Illinois Capital Development Board within 3 months after its completion. The Illinois Power Agency shall promptly make the results of each non-confidential report available for public inspection on its website.

(7) The Public Schools Carbon-Free Assessment shall be conducted in coordination with each utility's energy efficiency and demand-response plans under Sections 8-103, 8-103A, and 8-103B of this Act, to the extent applicable. Nothing in this Section is intended to modify or require modification of those plans. However, the utility may request a modification of a plan approved by the Commission, and the Commission may approve the requested modification, if the modification is consistent with the provisions of this Section and Section 8-103B of this Act.

(8) If there are no other providers of assessments that are substantively the same as those being performed by utilities pursuant to this Section by 2024, a utility that has a Public Schools Carbon-Free Assessment program may offer assessments to public schools that are not served by a utility subject to this Section at the utility's cost.

(9) The Public Schools Carbon-Free Assessment shall be offered to and performed for public schools in the utility's service territory on a complimentary basis by each utility, with no Assessment fee charged to the public schools for the Assessments. Nothing in this Section is intended to prohibit the utility from recovering through rates approved by the Commission the utility's prudent and reasonable costs of complying with this Section.

(10) Utilities shall make efforts to prioritize the completion of Public Schools Carbon-Free Assessments for the following school districts by December 31, 2022: East St. Louis School District 189, Harvey School District 152, Thornton Township High School District 205. Utilities shall also prioritize the completion of Public Schools Carbon-Free Assessments for schools located within environmental justice communities or schools that are categorized as a Tier 1 or Tier 2 school based on the latest annual evidence-based funding distribution process by the State Board of Education.

(Source: P.A. 102-662, eff. 9-15-21; 102-1123, eff. 1-27-23; 103-684, eff. 1-1-25.)

(220 ILCS 5/8-403) (from Ch. 111 2/3, par. 8-403)

Sec. 8-403. The Commission shall design and implement policies which encourage the economical utilization of cogeneration and small power production, as these terms are defined in Section 3-105, item (7) of subsection (b), including specifically, but not limited to, the cogeneration or production of heat, steam or electricity by municipal corporations or any other political subdivision of this State. No public utility shall discriminate in any way with respect to the conditions or price for provision of maintenance power, standby power and supplementary power as these terms are defined by current Commission rules, or for any other service. The prices charged by a utility for maintenance power, standby power, supplementary power and all other such services shall be cost-based and just and reasonable.

The Commission shall conduct a study of procedures and policies to encourage the full and economical utilization of cogeneration and small power production including, but not limited to, (1) requiring utilities to pay full avoided costs, including long-term avoided capacity costs to cogenerators and small power producers and (2) requiring utilities to make available upon request of the State or a unit of local government, transmission and distribution services to transmit electrical energy produced by cogeneration or small power production facilities located in any structure or on any real property of the State or unit of local government to other locations of this State or a unit of local government. The Commission shall report on this study, with recommendation for legislative consideration, to the General Assembly by March 1, 1986.

(Source: P.A. 95-481, eff. 8-28-07.)

(220 ILCS 5/8-403.1) (from Ch. 111 2/3, par. 8-403.1)

Sec. 8-403.1. Electricity purchased from qualified solid waste energy facility; tax credit; distributions for economic development.

(a) It is hereby declared to be the policy of this State to encourage the development of alternate energy production facilities in order to conserve our energy resources and to provide for their most efficient use.

(b) For the purpose of this Section and Section 9-215.1, "qualified solid waste energy facility" means a facility determined by the Illinois Commerce Commission to qualify as such under the Local Solid Waste Disposal Act, to use methane gas generated from landfills as its primary fuel, and to possess characteristics that would enable it to qualify as a cogeneration or small power production facility under federal law.

(c) In furtherance of the policy declared in this Section, the Illinois Commerce Commission shall require electric utilities to enter into long-term contracts to purchase electricity from qualified solid waste energy facilities located in the electric utility's service area, for a period beginning on the date that the facility begins generating electricity and having a duration of not less than 10 years in the case of facilities fueled by landfill-generated methane, or 20 years in the case of facilities fueled by methane generated from a landfill owned by a forest preserve district. The purchase rate contained in such contracts shall be equal to the average amount per kilowatt-hour paid from time to time by the unit or units of local government in which the electricity generating facilities are located, excluding amounts paid for street lighting and pumping service.

(d) Whenever a public utility is required to purchase electricity pursuant to subsection (c) above, it shall be entitled to credits in respect of its obligations to remit to the State taxes it has collected under the Electricity Excise Tax Law equal to the amounts, if any, by which payments for such electricity exceed (i) the then current rate at which the utility must purchase the output of qualified facilities pursuant to the federal Public Utility Regulatory Policies Act of 1978, less (ii) any costs, expenses, losses, damages or other amounts incurred by the utility, or for which it becomes liable, arising out of its failure to obtain such electricity from such other sources. The amount of any such credit shall, in the first instance, be determined by the utility, which shall make a monthly report of such credits to the Illinois Commerce Commission and, on its monthly tax return, to the Illinois Department of Revenue. Under no circumstances shall a utility be required to purchase electricity from a qualified solid waste energy facility at the rate prescribed in subsection (c) of this Section if such purchase would result in estimated tax credits that exceed, on a monthly basis, the utility's estimated obligation to remit to the State taxes it has collected under the Electricity Excise Tax Law. The owner or operator shall negotiate facility operating conditions with the purchasing utility in accordance with that utility's posted standard terms and conditions for small power producers. If the Department of Revenue disputes the amount of any such credit, such dispute shall be decided by the Illinois Commerce Commission. Whenever a qualified solid waste energy facility has paid or otherwise satisfied in full the capital costs or indebtedness incurred in developing and implementing the qualified solid waste energy facility, whenever the qualified solid waste energy facility ceases to operate and produce electricity from methane gas generated from landfills, or at the end of the contract entered into pursuant to subsection (c) of this Section, whichever occurs first, the qualified solid waste energy facility shall reimburse the Public Utility Fund and the General Revenue Fund in the State treasury for the actual reduction in payments to those Funds caused by this subsection (d) in a manner to be determined by the Illinois Commerce Commission and based on the manner in which revenues for those Funds were reduced. The payments shall be made to the Illinois Commerce Commission, which shall determine the appropriate disbursements to the Public Utility Fund and the General Revenue Fund based on this subsection (d).

(e) The Illinois Commerce Commission shall not require an electric utility to purchase electricity from any qualified solid waste energy facility which is owned or operated by an entity that is primarily engaged in the business of producing or selling electricity, gas, or useful thermal energy from a source other than one or more qualified solid waste energy facilities.

(e-5) A qualified solid waste energy facility may receive the purchase rate provided in subsection (c) of this Section only for kilowatt-hours generated by the use of methane gas generated from landfills. The purchase rate provided in subsection (c) of this Section does not apply to electricity generated by the use of a fuel that is not methane gas generated from landfills. If the Illinois Commerce Commission determines that a qualified solid waste energy facility has violated the requirement regarding the use of methane gas generated from a landfill as set forth in this subsection (e-5), then the Commission shall issue an order requiring that the qualified solid waste energy facility repay the State for all dollar amounts of electricity sales that are determined by the Commission to be the result of the violation. As part of that order, the Commission shall have the authority to revoke the facility's approval to act as a qualified solid waste energy facility granted by the Commission under this Section. If the amount owed by the qualified solid waste energy facility is not received by the Commission within 90 days after the date of the Commission's order that requires repayment, then the Commission shall issue an order that revokes the facility's approval to act as a qualified solid waste energy facility granted by the Commission under this Section. The Commission's action that vacates prior qualified solid waste energy facility approval does not excuse the repayment to the State treasury required by subsection (d) of this Section for utility tax credits accumulated up to the time of the Commission's action. A qualified solid waste energy facility must receive Commission approval before it may use any fuel in addition to methane gas generated from a landfill in order to generate electricity. If a qualified solid waste energy facility petitions the Commission to use any fuel in addition to methane gas generated from a landfill to generate electricity, then the Commission shall have the authority to do the following:

(1) establish the methodology for determining the amount of electricity that is generated by the use of methane gas generated from a landfill and the amount that is generated by the use of other fuel;

(2) determine all reporting requirements for the qualified solid waste energy facility that are necessary for the Commission to determine the amount of electricity that is generated by the use of methane gas from a landfill and the amount that is generated by the use of other fuel and the resulting payments to the qualified solid waste energy facility; and

(3) require that the qualified solid waste energy facility, at the qualified solid waste energy facility's expense, install metering equipment that the Commission determines is necessary to enforce compliance with this subsection (e-5).

A public utility that is required to enter into a long-term purchase contract with a qualified solid waste energy facility has no duty to determine whether the electricity being purchased was generated by the use of methane gas generated from a landfill or was generated by the use of some other fuel in violation of the requirements of this subsection (e-5).

(f) This Section does not require an electric utility to construct additional facilities unless those facilities are paid for by the owner or operator of the affected qualified solid waste energy facility.

(g) The Illinois Commerce Commission shall require that: (1) electric utilities use the electricity purchased from a qualified solid waste energy facility to displace electricity generated from nuclear power or coal mined and purchased outside the boundaries of the State of Illinois before displacing electricity generated from coal mined and purchased within the State of Illinois, to the extent possible, and (2) electric utilities report annually to the Commission on the extent of such displacements.

(h) Nothing in this Section is intended to cause an electric utility that is required to purchase power hereunder to incur any economic loss as a result of its purchase. All amounts paid for power which a utility is required to purchase pursuant to subparagraph (c) shall be deemed to be costs prudently incurred for purposes of computing charges under rates authorized by Section 9-220 of this Act. Tax credits provided for herein shall be reflected in charges made pursuant to rates so authorized to the extent such credits are based upon a cost which is also reflected in such charges.

(i) Beginning in February 1999 and through January 2013, each qualified solid waste energy facility that sells electricity to an electric utility at the purchase rate described in subsection (c) shall file with the Department of Revenue on or before the 15th of each month a form, prescribed by the Department of Revenue, that states the number of kilowatt hours of electricity for which payment was received at that purchase rate from electric utilities in Illinois during the immediately preceding month. This form shall be accompanied by a payment from the qualified solid waste energy facility in an amount equal to six-tenths of a mill ($0.0006) per kilowatt hour of electricity stated on the form. Beginning on the effective date of this amendatory Act of the 92nd General Assembly, a qualified solid waste energy facility must file the form required under this subsection (i) before the 15th of each month regardless of whether the facility received any payment in the previous month. Payments received by the Department of Revenue shall be deposited into the Municipal Economic Development Fund, a trust fund created outside the State treasury. The State Treasurer may invest the moneys in the Fund in any investment authorized by the Public Funds Investment Act, and investment income shall be deposited into and become part of the Fund. Moneys in the Fund shall be used by the State Treasurer as provided in subsection (j).

Beginning on July 1, 2006 through January 31, 2013, each month the State Treasurer shall certify the following to the State Comptroller:

(A) the amount received by the Department of Revenue under this subsection (i) during the immediately preceding month; and

(B) the amount received by the Department of Revenue under this subsection (i) in the corresponding month in calendar year 2002.

As soon as practicable after receiving the certification from the State Treasurer, the State Comptroller shall transfer from the General Revenue Fund to the Municipal Economic Development Fund in the State treasury an amount equal to the amount by which the amount calculated under item (B) of this paragraph exceeds the amount calculated under item (A) of this paragraph, if any.

The obligation of a qualified solid waste energy facility to make payments into the Municipal Economic Development Fund shall terminate upon either: (1) expiration or termination of a facility's contract to sell electricity to an electric utility at the purchase rate described in subsection (c); or (2) entry of an enforceable, final, and non-appealable order by a court of competent jurisdiction that Public Act 89-448 is invalid. Payments by a qualified solid waste energy facility into the Municipal Economic Development Fund do not relieve the qualified solid waste energy facility of its obligation to reimburse the Public Utility Fund and the General Revenue Fund for the actual reduction in payments to those Funds as a result of credits received by electric utilities under subsection (d).

A qualified solid waste energy facility that fails to timely file the requisite form and payment as required by this subsection (i) shall be subject to penalties and interest in conformance with the provisions of the Illinois Uniform Penalty and Interest Act.

Every qualified solid waste energy facility subject to the provisions of this subsection (i) shall keep and maintain records and books of its sales pursuant to subsection (c), including payments received from those sales and the corresponding tax payments made in accordance with this subsection (i), and for purposes of enforcement of this subsection (i) all such books and records shall be subject to inspection by the Department of Revenue or its duly authorized agents or employees.

When a qualified solid waste energy facility fails to file the form or make the payment required under this subsection (i), the Department of Revenue, to the extent that it is practical, may enforce the payment obligation in a manner consistent with Section 5 of the Retailers' Occupation Tax Act, and if necessary may impose and enforce a tax lien in a manner consistent with Sections 5a, 5b, 5c, 5d, 5e, 5f, 5g, and 5i of the Retailers' Occupation Tax Act. No tax lien may be imposed or enforced, however, unless a qualified solid waste energy facility fails to make the payment required under this subsection (i). Only to the extent necessary and for the purpose of enforcing this subsection (i), the Department of Revenue may secure necessary information from a qualified solid waste energy facility in a manner consistent with Section 10 of the Retailers' Occupation Tax Act.

All information received by the Department of Revenue in its administration and enforcement of this subsection (i) shall be confidential in a manner consistent with Section 11 of the Retailers' Occupation Tax Act. The Department of Revenue may adopt rules to implement the provisions of this subsection (i).

For purposes of implementing the maximum aggregate distribution provisions in subsections (j) and (k), when a qualified solid waste energy facility makes a late payment to the Department of Revenue for deposit into the Municipal Economic Development Fund, that payment and deposit shall be attributed to the month and corresponding quarter in which the payment should have been made, and the Treasurer shall make retroactive distributions or refunds, as the case may be, whenever such late payments so require.

(j) The State Treasurer, without appropriation, must make distributions immediately after January 15, April 15, July 15, and October 15 of each year, up to maximum aggregate distributions of $500,000 for the distributions made in the 4 quarters beginning with the April distribution and ending with the January distribution, from the Municipal Economic Development Fund to each city, village, or incorporated town located in Cook County that has approved construction within its boundaries of an incinerator that will burn recovered wood processed for fuel to generate electricity and will commence operation after 2009. Total distributions in the aggregate to all qualified cities, villages, and incorporated towns in the 4 quarters beginning with the April distribution and ending with the January distribution shall not exceed $500,000. The amount of each distribution shall be determined pro rata based on the population of the city, village, or incorporated town compared to the total population of all cities, villages, and incorporated towns eligible to receive a distribution. Distributions received by a city, village, or incorporated town must be held in a separate account and may be used only to promote and enhance industrial, commercial, residential, service, transportation, and recreational activities and facilities within its boundaries, thereby enhancing the employment opportunities, public health and general welfare, and economic development within the community, including administrative expenditures exclusively to further these activities. Distributions may also be used for cleanup of open dumping from vacant properties and the removal of structures condemned by the city, village, or incorporated town. These funds, however, shall not be used by the city, village, or incorporated town, directly or indirectly, to purchase, lease, operate, or in any way subsidize the operation of any incinerator, and these funds shall not be paid, directly or indirectly, by the city, village, or incorporated town to the owner, operator, lessee, shareholder, or bondholder of any incinerator. Moreover, these funds shall not be used to pay attorneys fees in any litigation relating to the validity of Public Act 89-448. Nothing in this Section prevents a city, village, or incorporated town from using other corporate funds for any legitimate purpose. For purposes of this subsection, the term "municipal waste" has the meaning ascribed to it in Section 3.290 of the Environmental Protection Act.

(k) If maximum aggregate distributions of $500,000 under subsection (j) have been made after the January distribution from the Municipal Economic Development Fund, then the balance in the Fund shall be refunded to the qualified solid waste energy facilities that made payments that were deposited into the Fund during the previous 12-month period. The refunds shall be prorated based upon the facility's payments in relation to total payments for that 12-month period.

(l) Beginning January 1, 2000, and each January 1 thereafter, each city, village, or incorporated town that received distributions from the Municipal Economic Development Fund, continued to hold any of those distributions, or made expenditures from those distributions during the immediately preceding year shall submit to a financial and compliance and program audit of those distributions performed by the Auditor General at no cost to the city, village, or incorporated town that received the distributions. The audit should be completed by June 30 or as soon thereafter as possible. The audit shall be submitted to the State Treasurer and those officers enumerated in Section 3-14 of the Illinois State Auditing Act. If the Auditor General finds that distributions have been expended in violation of this Section, the Auditor General shall refer the matter to the Attorney General. The Attorney General may recover, in a civil action, 3 times the amount of any distributions illegally expended. For purposes of this subsection, the terms "financial audit," "compliance audit", and "program audit" have the meanings ascribed to them in Sections 1-13 and 1-15 of the Illinois State Auditing Act.

(m) On and after the effective date of this amendatory Act of the 94th General Assembly, beginning on the first date on which renewable energy certificates or other saleable representations are sold by a qualified solid waste energy facility, with or without the electricity generated by the facility, and utilized by an electric utility or another electric supplier to comply with a renewable energy portfolio standard mandated by Illinois law or mandated by order of the Illinois Commerce Commission, that qualified solid waste energy facility may not sell electricity pursuant to this Section and shall be exempt from the requirements of subsections (a) through (l) of this Section, except that it shall remain obligated for any reimbursements required under subsection (d) of this Section. All of the provisions of this Section shall remain in full force and effect with respect to any qualified solid waste energy facility that sold electric energy pursuant to this Section at any time before July 1, 2006 and that does not sell renewable energy certificates or other saleable representations to meet the requirements of a renewable energy portfolio standard mandated by Illinois law or mandated by order of the Illinois Commerce Commission.

(n) Notwithstanding any other provision of law to the contrary, beginning on July 1, 2006, the Illinois Commerce Commission shall not issue any order determining that a facility is a qualified solid waste energy facility unless the qualified solid waste energy facility was determined by the Illinois Commerce Commission to be a qualified solid waste energy facility before July 1, 2006. As a guide to the intent, interpretation, and application of this amendatory Act of the 94th General Assembly, it is hereby declared to be the policy of this State to honor each qualified solid waste energy facility contract in existence on the effective date of this amendatory Act of the 94th General Assembly if the qualified solid waste energy facility continues to meet the requirements of this Section for the duration of its respective contract term.

(Source: P.A. 96-449, eff. 8-14-09.)

(220 ILCS 5/8-404) (from Ch. 111 2/3, par. 8-404)

Sec. 8-404. (Repealed).

(Source: P.A. 87-812. Repealed by P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/8-405)

Sec. 8-405. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/8-405.1)

Sec. 8-405.1. (Repealed).

(Source: P.A. 89-445, eff. 2-7-96. Repealed by P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/8-406) (from Ch. 111 2/3, par. 8-406)

Sec. 8-406. Certificate of public convenience and necessity.

(a) No public utility not owning any city or village franchise nor engaged in performing any public service or in furnishing any product or commodity within this State as of July 1, 1921 and not possessing a certificate of public convenience and necessity from the Illinois Commerce Commission, the State Public Utilities Commission, or the Public Utilities Commission, at the time Public Act 84-617 goes into effect (January 1, 1986), shall transact any business in this State until it shall have obtained a certificate from the Commission that public convenience and necessity require the transaction of such business. A certificate of public convenience and necessity requiring the transaction of public utility business in any area of this State shall include authorization to the public utility receiving the certificate of public convenience and necessity to construct such plant, equipment, property, or facility as is provided for under the terms and conditions of its tariff and as is necessary to provide utility service and carry out the transaction of public utility business by the public utility in the designated area.

(b) No public utility shall begin the construction of any new plant, equipment, property, or facility which is not in substitution of any existing plant, equipment, property, or facility, or any extension or alteration thereof or in addition thereto, unless and until it shall have obtained from the Commission a certificate that public convenience and necessity require such construction. Whenever after a hearing the Commission determines that any new construction or the transaction of any business by a public utility will promote the public convenience and is necessary thereto, it shall have the power to issue certificates of public convenience and necessity. The Commission shall determine that proposed construction will promote the public convenience and necessity only if the utility demonstrates: (1) that the proposed construction is necessary to provide adequate, reliable, and efficient service to its customers and is the least-cost means of satisfying the service needs of its customers or that the proposed construction will promote the development of an effectively competitive electricity market that operates efficiently, is equitable to all customers, and is the least cost means of satisfying those objectives; (2) that the utility is capable of efficiently managing and supervising the construction process and has taken sufficient action to ensure adequate and efficient construction and supervision thereof; and (3) that the utility is capable of financing the proposed construction without significant adverse financial consequences for the utility or its customers.

(b-5) As used in this subsection (b-5):

"Qualifying direct current applicant" means an entity that seeks to provide direct current bulk transmission service for the purpose of transporting electric energy in interstate commerce.

"Qualifying direct current project" means a high voltage direct current electric service line that crosses at least one Illinois border, the Illinois portion of which is physically located within the region of the Midcontinent Independent System Operator, Inc., or its successor organization, and runs through the counties of Pike, Scott, Greene, Macoupin, Montgomery, Christian, Shelby, Cumberland, and Clark, is capable of transmitting electricity at voltages of 345 kilovolts or above, and may also include associated interconnected alternating current interconnection facilities in this State that are part of the proposed project and reasonably necessary to connect the project with other portions of the grid.

Notwithstanding any other provision of this Act, a qualifying direct current applicant that does not own, control, operate, or manage, within this State, any plant, equipment, or property used or to be used for the transmission of electricity at the time of its application or of the Commission's order may file an application on or before December 31, 2023 with the Commission pursuant to this Section or Section 8-406.1 for, and the Commission may grant, a certificate of public convenience and necessity to construct, operate, and maintain a qualifying direct current project. The qualifying direct current applicant may also include in the application requests for authority under Section 8-503. The Commission shall grant the application for a certificate of public convenience and necessity and requests for authority under Section 8-503 if it finds that the qualifying direct current applicant and the proposed qualifying direct current project satisfy the requirements of this subsection and otherwise satisfy the criteria of this Section or Section 8-406.1 and the criteria of Section 8-503, as applicable to the application and to the extent such criteria are not superseded by the provisions of this subsection. The Commission's order on the application for the certificate of public convenience and necessity shall also include the Commission's findings and determinations on the request or requests for authority pursuant to Section 8-503. Prior to filing its application under either this Section or Section 8-406.1, the qualifying direct current applicant shall conduct 3 public meetings in accordance with subsection (h) of this Section. If the qualifying direct current applicant demonstrates in its application that the proposed qualifying direct current project is designed to deliver electricity to a point or points on the electric transmission grid in either or both the PJM Interconnection, LLC or the Midcontinent Independent System Operator, Inc., or their respective successor organizations, the proposed qualifying direct current project shall be deemed to be, and the Commission shall find it to be, for public use. If the qualifying direct current applicant further demonstrates in its application that the proposed transmission project has a capacity of 1,000 megawatts or larger and a voltage level of 345 kilovolts or greater, the proposed transmission project shall be deemed to satisfy, and the Commission shall find that it satisfies, the criteria stated in item (1) of subsection (b) of this Section or in paragraph (1) of subsection (f) of Section 8-406.1, as applicable to the application, without the taking of additional evidence on these criteria. Prior to the transfer of functional control of any transmission assets to a regional transmission organization, a qualifying direct current applicant shall request Commission approval to join a regional transmission organization in an application filed pursuant to this subsection (b-5) or separately pursuant to Section 7-102 of this Act. The Commission may grant permission to a qualifying direct current applicant to join a regional transmission organization if it finds that the membership, and associated transfer of functional control of transmission assets, benefits Illinois customers in light of the attendant costs and is otherwise in the public interest. Nothing in this subsection (b-5) requires a qualifying direct current applicant to join a regional transmission organization. Nothing in this subsection (b-5) requires the owner or operator of a high voltage direct current transmission line that is not a qualifying direct current project to obtain a certificate of public convenience and necessity to the extent it is not otherwise required by this Section 8-406 or any other provision of this Act.

(c) As used in this subsection (c):

"Decommissioning" has the meaning given to that term in subsection (a) of Section 8-508.1.

"Nuclear power reactor" has the meaning given to that term in Section 8 of the Nuclear Safety Law of 2004.

After the effective date of this amendatory Act of the 103rd General Assembly, no construction shall commence on any new nuclear power reactor with a nameplate capacity of more than 300 megawatts of electricity to be located within this State, and no certificate of public convenience and necessity or other authorization shall be issued therefor by the Commission, until the Illinois Emergency Management Agency and Office of Homeland Security, in consultation with the Illinois Environmental Protection Agency and the Illinois Department of Natural Resources, finds that the United States Government, through its authorized agency, has identified and approved a demonstrable technology or means for the disposal of high level nuclear waste, or until such construction has been specifically approved by a statute enacted by the General Assembly. Beginning January 1, 2026, construction may commence on a new nuclear power reactor with a nameplate capacity of 300 megawatts of electricity or less within this State if the entity constructing the new nuclear power reactor has obtained all permits, licenses, permissions, or approvals governing the construction, operation, and funding of decommissioning of such nuclear power reactors required by: (1) this Act; (2) any rules adopted by the Illinois Emergency Management Agency and Office of Homeland Security under the authority of this Act; (3) any applicable federal statutes, including, but not limited to, the Atomic Energy Act of 1954, the Energy Reorganization Act of 1974, the Low-Level Radioactive Waste Policy Amendments Act of 1985, and the Energy Policy Act of 1992; (4) any regulations promulgated or enforced by the U.S. Nuclear Regulatory Commission, including, but not limited to, those codified at Title X, Parts 20, 30, 40, 50, 70, and 72 of the Code of Federal Regulations, as from time to time amended; and (5) any other federal or State statute, rule, or regulation governing the permitting, licensing, operation, or decommissioning of such nuclear power reactors. None of the rules developed by the Illinois Emergency Management Agency and Office of Homeland Security or any other State agency, board, or commission pursuant to this Act shall be construed to supersede the authority of the U.S. Nuclear Regulatory Commission. The changes made by this amendatory Act of the 103rd General Assembly shall not apply to the uprate, renewal, or subsequent renewal of any license for an existing nuclear power reactor that began operation prior to the effective date of this amendatory Act of the 103rd General Assembly.

None of the changes made in this amendatory Act of the 103rd General Assembly are intended to authorize the construction of nuclear power plants powered by nuclear power reactors that are not either: (1) small modular nuclear reactors; or (2) nuclear power reactors licensed by the U.S. Nuclear Regulatory Commission to operate in this State prior to the effective date of this amendatory Act of the 103rd General Assembly.

(d) In making its determination under subsection (b) of this Section, the Commission shall attach primary weight to the cost or cost savings to the customers of the utility. The Commission may consider any or all factors which will or may affect such cost or cost savings, including the public utility's engineering judgment regarding the materials used for construction.

(e) The Commission may issue a temporary certificate which shall remain in force not to exceed one year in cases of emergency, to assure maintenance of adequate service or to serve particular customers, without notice or hearing, pending the determination of an application for a certificate, and may by regulation exempt from the requirements of this Section temporary acts or operations for which the issuance of a certificate will not be required in the public interest.

A public utility shall not be required to obtain but may apply for and obtain a certificate of public convenience and necessity pursuant to this Section with respect to any matter as to which it has received the authorization or order of the Commission under the Electric Supplier Act, and any such authorization or order granted a public utility by the Commission under that Act shall as between public utilities be deemed to be, and shall have except as provided in that Act the same force and effect as, a certificate of public convenience and necessity issued pursuant to this Section.

No electric cooperative shall be made or shall become a party to or shall be entitled to be heard or to otherwise appear or participate in any proceeding initiated under this Section for authorization of power plant construction and as to matters as to which a remedy is available under the Electric Supplier Act.

(f) Such certificates may be altered or modified by the Commission, upon its own motion or upon application by the person or corporation affected. Unless exercised within a period of 2 years from the grant thereof, authority conferred by a certificate of convenience and necessity issued by the Commission shall be null and void.

No certificate of public convenience and necessity shall be construed as granting a monopoly or an exclusive privilege, immunity or franchise.

(g) A public utility that undertakes any of the actions described in items (1) through (3) of this subsection (g) or that has obtained approval pursuant to Section 8-406.1 of this Act shall not be required to comply with the requirements of this Section to the extent such requirements otherwise would apply. For purposes of this Section and Section 8-406.1 of this Act, "high voltage electric service line" means an electric line having a design voltage of 100,000 or more. For purposes of this subsection (g), a public utility may do any of the following:

(1) replace or upgrade any existing high voltage electric service line and related facilities, notwithstanding its length;

(2) relocate any existing high voltage electric service line and related facilities, notwithstanding its length, to accommodate construction or expansion of a roadway or other transportation infrastructure; or

(3) construct a high voltage electric service line and related facilities that is constructed solely to serve a single customer's premises or to provide a generator interconnection to the public utility's transmission system and that will pass under or over the premises owned by the customer or generator to be served or under or over premises for which the customer or generator has secured the necessary right of way.

(h) A public utility seeking to construct a high-voltage electric service line and related facilities (Project) must show that the utility has held a minimum of 2 pre-filing public meetings to receive public comment concerning the Project in each county where the Project is to be located, no earlier than 6 months prior to filing an application for a certificate of public convenience and necessity from the Commission. Notice of the public meeting shall be published in a newspaper of general circulation within the affected county once a week for 3 consecutive weeks, beginning no earlier than one month prior to the first public meeting. If the Project traverses 2 contiguous counties and where in one county the transmission line mileage and number of landowners over whose property the proposed route traverses is one-fifth or less of the transmission line mileage and number of such landowners of the other county, then the utility may combine the 2 pre-filing meetings in the county with the greater transmission line mileage and affected landowners. All other requirements regarding pre-filing meetings shall apply in both counties. Notice of the public meeting, including a description of the Project, must be provided in writing to the clerk of each county where the Project is to be located. A representative of the Commission shall be invited to each pre-filing public meeting.

(i) For applications filed after August 18, 2015 (the effective date of Public Act 99-399), the Commission shall, by certified mail, notify each owner of record of land, as identified in the records of the relevant county tax assessor, included in the right-of-way over which the utility seeks in its application to construct a high-voltage electric line of the time and place scheduled for the initial hearing on the public utility's application. The utility shall reimburse the Commission for the cost of the postage and supplies incurred for mailing the notice.

(Source: P.A. 102-609, eff. 8-27-21; 102-662, eff. 9-15-21; 102-813, eff. 5-13-22; 102-931, eff. 5-27-22; 103-569, eff. 6-1-24.)

(220 ILCS 5/8-406.1)

Sec. 8-406.1. Certificate of public convenience and necessity; expedited procedure.

(a) A public utility may apply for a certificate of public convenience and necessity pursuant to this Section for the construction of any new high voltage electric service line and related facilities (Project). To facilitate the expedited review process of an application filed pursuant to this Section, an application shall include all of the following:

(1) Information in support of the application that shall include the following:

(A) A detailed description of the Project, including location maps and plot plans to scale showing all major components.

(B) The following engineering data:

(i) a detailed Project description including:

(I) name and destination of the Project;

(II) design voltage rating (kV);

(III) operating voltage rating (kV); and

(IV) normal peak operating current rating;

(ii) a conductor, structures, and substations description including:

(I) conductor size and type;

(II) type of structures;

(III) height of typical structures;

(IV) an explanation why these structures were selected;

(V) dimensional drawings of the typical structures to be used in the Project; and

(VI) a list of the names of all new (and existing if applicable) substations or switching stations that will be associated with the proposed new high voltage electric service line;

(iii) the location of the site and right-of-way including:

(I) miles of right-of-way;

(II) miles of circuit;

(III) width of the right-of-way; and

(IV) a brief description of the area traversed by the proposed high voltage electric service line, including a description of the general land uses in the area and the type of terrain crossed by the proposed line;

(iv) assumptions, bases, formulae, and methods used in the development and preparation of the diagrams and accompanying data, and a technical description providing the following information:

(I) number of circuits, with identification as to whether the circuit is overhead or underground;

(II) the operating voltage and frequency; and

(III) conductor size and type and number of conductors per phase;

(v) if the proposed interconnection is an overhead line, the following additional information also must be provided:

(I) the wind and ice loading design parameters;

(II) a full description and drawing of a typical supporting structure, including strength specifications;

(III) structure spacing with typical ruling and maximum spans;

(IV) conductor (phase) spacing; and

(V) the designed line-to-ground and conductor-side clearances;

(vi) if an underground or underwater interconnection is proposed, the following additional information also must be provided:

(I) burial depth;

(II) type of cable and a description of any required supporting equipment, such as insulation medium pressurizing or forced cooling;

(III) cathodic protection scheme; and

(IV) type of dielectric fluid and safeguards used to limit potential spills in waterways;

(vii) technical diagrams that provide clarification of any item under this item (1) should be included; and

(viii) applicant shall provide and identify a primary right-of-way and one or more alternate rights-of-way for the Project as part of the filing. To the extent applicable, for each right-of-way, an applicant shall provide the information described in this subsection (a). Upon a showing of good cause in its filing, an applicant may be excused from providing and identifying alternate rights-of-way.

(2) An application fee of $100,000, which shall be paid into the Public Utility Fund at the time the Chief Clerk of the Commission deems it complete and accepts the filing.

(3) Information showing that the utility has held a minimum of 3 pre-filing public meetings to receive public comment concerning the Project in each county where the Project is to be located, no earlier than 6 months prior to the filing of the application. Notice of the public meeting shall be published in a newspaper of general circulation within the affected county once a week for 3 consecutive weeks, beginning no earlier than one month prior to the first public meeting. If the Project traverses 2 contiguous counties and where in one county the transmission line mileage and number of landowners over whose property the proposed route traverses is 1/5 or less of the transmission line mileage and number of such landowners of the other county, then the utility may combine the 3 pre-filing meetings in the county with the greater transmission line mileage and affected landowners. All other requirements regarding pre-filing meetings shall apply in both counties. Notice of the public meeting, including a description of the Project, must be provided in writing to the clerk of each county where the Project is to be located. A representative of the Commission shall be invited to each pre-filing public meeting.

For applications filed after the effective date of this amendatory Act of the 99th General Assembly, the Commission shall, by certified mail, notify each owner of record of the land, as identified in the records of the relevant county tax assessor, included in the primary or alternate rights-of-way identified in the utility's application of the time and place scheduled for the initial hearing upon the public utility's application. The utility shall reimburse the Commission for the cost of the postage and supplies incurred for mailing the notice.

(b) At the first status hearing the administrative law judge shall set a schedule for discovery that shall take into consideration the expedited nature of the proceeding.

(c) Nothing in this Section prohibits a utility from requesting, or the Commission from approving, protection of confidential or proprietary information under applicable law. The public utility may seek confidential protection of any of the information provided pursuant to this Section, subject to Commission approval.

(d) The public utility shall publish notice of its application in the official State newspaper within 10 days following the date of the application's filing.

(e) The public utility shall establish a dedicated website for the Project 3 weeks prior to the first public meeting and maintain the website until construction of the Project is complete. The website address shall be included in all public notices.

(f) The Commission shall, after notice and hearing, grant a certificate of public convenience and necessity filed in accordance with the requirements of this Section if, based upon the application filed with the Commission and the evidentiary record, it finds the Project will promote the public convenience and necessity and that all of the following criteria are satisfied:

(1) That the Project is necessary to provide adequate, reliable, and efficient service to the public utility's customers and is the least-cost means of satisfying the service needs of the public utility's customers or that the Project will promote the development of an effectively competitive electricity market that operates efficiently, is equitable to all customers, and is the least cost means of satisfying those objectives.

(2) That the public utility is capable of efficiently managing and supervising the construction process and has taken sufficient action to ensure adequate and efficient construction and supervision of the construction.

(3) That the public utility is capable of financing the proposed construction without significant adverse financial consequences for the utility or its customers.

(g) The Commission shall issue its decision with findings of fact and conclusions of law granting or denying the application no later than 150 days after the application is filed. The Commission may extend the 150-day deadline upon notice by an additional 75 days if, on or before the 30th day after the filing of the application, the Commission finds that good cause exists to extend the 150-day period.

(h) In the event the Commission grants a public utility's application for a certificate pursuant to this Section, the public utility shall pay a one-time construction fee to each county in which the Project is constructed within 30 days after the completion of construction. The construction fee shall be $20,000 per mile of high voltage electric service line constructed in that county, or a proportionate fraction of that fee. The fee shall be in lieu of any permitting fees that otherwise would be imposed by a county. Counties receiving a payment under this subsection (h) may distribute all or portions of the fee to local taxing districts in that county.

(i) Notwithstanding any other provisions of this Act, a decision granting a certificate under this Section shall include an order pursuant to Section 8-503 of this Act authorizing or directing the construction of the high voltage electric service line and related facilities as approved by the Commission, in the manner and within the time specified in said order.

(Source: P.A. 102-931, eff. 5-27-22.)

(220 ILCS 5/8-406.2)

Sec. 8-406.2. Certificate of public convenience and necessity; extension of utility service area and facilities to serve designated hardship areas.

(a) This Section is intended to provide a mechanism by which a gas public utility may extend its service territory and gas distribution system to provide service to designated low-income areas whose residents do not have access to natural gas service and must purchase more costly alternatives to satisfy their energy needs.

(b) In this Section:

"Designated hardship area" is limited to Pembroke Township, if the Township meets certain requirements. Any "designated hardship area" only applies to the specific community of Pembroke within the scope of the Project. Pembroke Township will only be categorized as a "designated hardship area" if it meets the following requirements:

(1) the area is designated as a qualified census tract by the U.S. Department of Housing and Urban Development as published in the most current Federal Register; if the U.S. Department of Housing and Urban Development ceases to make this designation, then at least 25% of the households in the area are at or below the poverty level; and

(2) the area is not currently served by a gas utility.

"Hardship area facilities" means all gas distribution system facilities that are proposed to be constructed or extended and used to serve the designated hardship area, through and including retail gas meters. "Hardship area facilities" includes the capacity to address reasonably foreseeable growth in areas adjacent to or in the vicinity of the designated hardship area.

(c) A gas public utility may apply for a certificate of public convenience and necessity pursuant to this Section to increase its gas service territory and extend its gas distribution system to serve a designated hardship area. An application under this Section shall include all of the following:

(1) a description of the designated hardship area and its relationship to the existing gas distribution system of the applicant;

(2) a showing that the designated hardship area meets the criteria for being a designated hardship area under subsection (b) of this Section;

(3) a description of the hardship area facilities proposed to serve the designated hardship area;

(4) a projection of the costs to construct and deploy the hardship area facilities;

(5) a showing that the estimated cost to construct and deploy the hardship area facilities is equal to or less than 250% of the amount allowed under the gas utilities' then current tariffs to provide standard service to extend main and services; and

(6) a statement to confirm that the public utility has held at least 2 pre-filing public meetings in the community and considered public input from those meetings when developing and implementing its plans.

(d) The Commission shall, after notice and hearing, grant a certificate of public convenience and necessity under this Section if, based upon the application filed with the Commission and the evidentiary record, the Commission finds that all of the following criteria are satisfied:

(1) the area to be served is a designated hardship area;

(2) the proposed hardship area facilities will provide adequate, reliable, and efficient gas delivery service to the customers within the designated hardship area and are the least-cost means of providing such gas delivery service to these customers;

(3) the public utility is capable of efficiently managing and supervising the construction of the hardship area facilities and has taken sufficient action to ensure adequate and efficient construction and supervision of the construction;

(4) the public utility is capable of financing the construction of the hardship area facilities without significant adverse financial consequences for the utility or its customers;

(5) the estimated cost to construct and deploy the hardship area facilities is equal to or less than 250% of the amount allowed under the gas utilities then current tariffs to provide standard service to extend main and services;

(6) the public utility can guarantee that residents of Hopkins Park who choose to opt out of converting to a natural gas delivery service will not be assessed any charges relating to the pipeline construction or any other fees relating to the designated hardship area facilities;

(7) the public utility disclosed to the Commission the mapping of the proposed pipeline and infrastructure management requirements within the designated hardship area; and

(8) the public utility has guaranteed that, before implementation, it will disclose to the Commission the cost to the utility for customers of Hopkins Park to utilize gas services.

(e) The Commission shall issue its decision with findings of fact and conclusions of law granting or denying the application no later than 120 days after the application is filed.

(Source: P.A. 102-609, eff. 8-27-21.)

(220 ILCS 5/8-407) (from Ch. 111 2/3, par. 8-407)

Sec. 8-407. (a) The Commission, after granting any certificate of public convenience and necessity for the construction of a new electric generating facility, shall reevaluate the propriety and necessity for the certificate at least every 3 years and shall consider in the reevaluation any and all changes in the forecasts and circumstances relied upon in its initial decision to grant the certificate, including but not limited to, each criterion that is outlined in this Section as a precondition for the granting of a certificate and any changes in the energy plans for the utility and the State.

(b) Whenever the Commission grants any certificate of public convenience and necessity for the construction of a new electric generating facility, the Commission shall design and establish all procedures necessary for it to thoroughly and effectively evaluate, supervise, and monitor construction, and shall thereafter take all steps necessary to assure that construction is efficient and economical.

The Commission shall have the power to conduct a construction cost audit at any time during construction, or to arrange for such an audit to be conducted by persons independent of the utility and selected by the Commission, whenever the Commission has cause to believe that such audit is necessary, or likely to be beneficial, to the efficiency or economy of construction. The cost of such an independent audit shall be borne initially by the utility, but shall be recovered as an expense through normal ratemaking procedures pursuant to this Act.

(c) The Commission shall have the power to withdraw or alter any certificate of public convenience and necessity including any certificate granted for the construction of a new electric generating facility or a substantial alteration or addition to an existing generating facility where it determines that:

(i) circumstances have changed so substantially that continued construction is no longer necessary or beneficial to ratepayers; or

(ii) the utility has failed to substantially comply with the requirements and conditions of its certificate or subsequent Commission orders with respect to the construction process.

(Source: P.A. 87-959.)

(220 ILCS 5/8-408)

Sec. 8-408. Energy efficiency plans for small multi-jurisdictional utilities.

(a) Any electric or gas public utility with fewer than 200,000 customers in Illinois on January 1, 2007 that offers energy efficiency programs to its customers in a state adjacent to Illinois may seek the approval of the Commission to offer the same or comparable energy efficiency programs to its customers in Illinois. For each program to be offered, the utility shall submit to the Commission:

(1) a description of the program;

(2) a proposed implementation schedule and method;

(3) the number of eligible participants;

(4) the expected rate of participation per year;

(5) the estimated annual peak demand and energy savings;

(6) the budget or level of spending; and

(7) the rate impacts and average bill impacts, by customer class, resulting from the program.

The Commission shall approve each program demonstrated to be cost-effective. Programs for low-income customers shall be approved by the Commission even if they have not been demonstrated to be cost-effective if they are demonstrated to be reasonable. An order of the State agency that regulates the rates of the utility in the adjacent state that finds a program to be cost-effective or reasonable shall be sufficient to demonstrate that the program is cost-effective or reasonable for the utility's customers in Illinois. Approved programs may be delivered by the utility or by a contractor or agent of the utility.

(b) Notwithstanding the provisions of Section 9-201, a public utility providing approved energy efficiency programs in the State shall be permitted to recover the reasonable costs of those programs through an automatic adjustment clause tariff filed with and approved by the Commission. Each year the Commission shall initiate a review to reconcile any amounts collected with the actual costs and to determine the adjustment to the annual tariff factor to match annual expenditures. The determination shall be made within 90 days after the date of initiation of the review.

(c) The utility may request a waiver of one or more components of an approved energy efficiency program at any time in order to improve the program's effectiveness. The Commission may grant the waiver if good cause is shown by the utility. Notwithstanding the cessation of the programs, a utility shall file a final reconciliation of the amounts collected as compared to the actual costs and shall continue the resulting factor until any over-recovery or under-recovery approaches zero.

(d) A public utility that offers approved energy efficiency programs in the State may do so through at least December 31, 2012. The Commission shall monitor the performance of the energy efficiency programs and, on or before October 31, 2012, the Commission shall make a determination regarding whether the programs should be continued beyond calendar year 2012. The Commission shall also file a written report with the General Assembly explaining the basis for that determination and detailing the results of the energy efficiency programs, including energy savings, participation numbers, and costs.

(Source: P.A. 95-660, eff. 1-1-08.)

(220 ILCS 5/8-501) (from Ch. 111 2/3, par. 8-501)

Sec. 8-501. Whenever the Commission, after a hearing had upon its own motion or upon complaint, shall find that the rules, regulations, practices, equipment, appliances, facilities or service of any public utility, or the methods of manufacture, distribution, transmission, storage or supply employed by it, are unjust, unreasonable, unsafe, improper, inadequate or insufficient, the Commission shall determine the just, reasonable, safe, proper, adequate or sufficient rules, regulations, practices, equipment, appliances, facilities, service or methods to be observed, furnished, constructed, enforced or employed and it shall fix the same by its order, decision, rule or regulation. The Commission shall prescribe rules and regulations for the performance of any service or the furnishing of any commodity of the character furnished or supplied by any public utility.

Whenever the Commission shall determine, after a hearing, that the public convenience and necessity requires that interconnection or extension of intrastate gas distribution or transmission pipelines or facilities is necessary to insure that natural gas service is made available to Illinois natural gas customers at rates which are just and reasonable, the Commission shall determine the interconnection or extension of pipelines or facilities which is necessary to provide such service and shall direct that such facilities be established, according to a schedule set by the Commission. The Commission shall direct that any utility supplying natural gas for such interconnection or extension of intrastate gas distribution or transmission pipelines or facilities shall recover all costs and charges related to the interconnection or extension from the utility receiving such gas at no increased cost to the customers of any utility supplying the gas. The Commission is directed to report to the General Assembly by September 20, 1984, detailing its findings and the steps which it has taken to provide for such intrastate interconnections or extensions.

(Source: P.A. 84-617.)

(220 ILCS 5/8-501.5)

Sec. 8-501.5. Employees and independent contractors; background checks.

(a) Before hiring an employee or independent contractor to perform work involving facilities used for the distribution of natural gas to customers, a public utility shall, in accordance with Commission rules, require the proposed employee or independent contractor to complete a certificate listing the proposed employee's or contractor's violations of pertinent safety or environmental laws.

(b) The Commission shall adopt rules establishing the requirements for the certificates referred to in subsection (a).

(Source: P.A. 92-71, eff. 7-12-01.)

(220 ILCS 5/8-502) (from Ch. 111 2/3, par. 8-502)

Sec. 8-502. Whenever the Commission, after a hearing had upon its own motion or upon complaint, shall find that public convenience and necessity require the use by one public utility of the conduits, subways, wires, poles, pipes or other property or equipment, or any part thereof, on, over or under any street or highway, belonging to another public utility, and that such use will not prevent the owner or other users thereof from performing their public duties nor result in irreparable injury to such owner or other users of such conduits, subways, wires, poles, pipes or other property or equipment, or in any substantial detriment to the service, and that such public utilities have failed to agree upon such use or the terms and conditions or compensation for the same, the Commission may, by order, direct that such use be permitted and prescribe a reasonable compensation and reasonable terms and conditions for such joint use. If such use be directed, the public utility to whom the use is permitted shall be liable to the owner or other users of such conduits, subways, wires, poles, pipes or other property or equipment, for such damage as may result therefrom to the property of such owner or other users thereof.

(Source: P.A. 84-1308.)

(220 ILCS 5/8-503) (from Ch. 111 2/3, par. 8-503)

Sec. 8-503. Whenever the Commission, after a hearing, shall find that additions, extensions, repairs or improvements to, or changes in, the existing plant, equipment, apparatus, facilities or other physical property of any public utility or of any 2 or more public utilities are necessary and ought reasonably to be made or that a new structure or structures is or are necessary and should be erected, to promote the security or convenience of its employees or the public or promote the development of an effectively competitive electricity market, or in any other way to secure adequate service or facilities, the Commission shall make and serve an order authorizing or directing that such additions, extensions, repairs, improvements or changes be made, or such structure or structures be erected at the location, in the manner and within the time specified in said order; provided, however, that the Commission shall have no authority to order the construction, addition or extension of any electric generating plant unless the public utility requests a certificate for the construction of the plant pursuant to Section 8-406 and in conjunction with such request also requests the entry of an order under this Section. If any additions, extensions, repairs, improvements or changes, or any new structure or structures, which the Commission has authorized or ordered to be erected, require joint action by 2 or more public utilities, the Commission shall notify the said public utilities that such additions, extensions, repairs, improvements or changes or new structure or structures have been authorized or ordered and that the same shall be made at the joint cost whereupon the said public utilities shall have such reasonable time as the Commission may grant within which to agree upon the apportionment or division of cost of such additions, extensions, repairs, improvements or changes or new structure or structures, which each shall bear. If at the expiration of such time such public utilities shall fail to file with the Commission a statement that an agreement has been made for a division or apportionment of the cost or expense of such additions, extensions, repairs, improvements or changes, or new structure or structures, the Commission shall have authority, after further hearing, to make an order fixing the proportion of such cost or expense to be borne by each public utility and the manner in which the same shall be paid or secured.

Nothing in this Act shall prevent the Commission, upon its own motion or upon petition, from ordering, after a hearing, the extension, construction, connection or interconnection of plant, equipment, pipe, line, facilities or other physical property of a public utility in whatever configuration the Commission finds necessary to ensure that natural gas is made available to consumers at no increased cost to the customers of the utility supplying the gas.

Whenever the Commission finds, after a hearing, that the public convenience or necessity requires it, the Commission may order public utilities subject to its jurisdiction to work jointly (1) for the purpose of purchasing and distributing natural gas or gas substitutes, provided it shall not increase the cost of gas to the customers of the participating utilities, or (2) for any other reasonable purpose.

(Source: P.A. 95-700, eff. 11-9-07.)

(220 ILCS 5/8-504) (from Ch. 111 2/3, par. 8-504)

Sec. 8-504. The Commission is authorized to make rules and regulations concerning the conditions to be contained in and become a part of contracts for public utility services, and any and all services concerning the same, or connected therewith.

(Source: P.A. 84-617.)

(220 ILCS 5/8-505) (from Ch. 111 2/3, par. 8-505)

Sec. 8-505. The Commission shall have power, after a hearing or without a hearing as provided in this Section and upon its own motion, or upon complaint, by general or special orders, rules or regulations, or otherwise, to require every public utility to maintain and operate its plant, equipment or other property in such manner as to promote and safeguard the health and safety of its employees, customers, and the public, and to this end to prescribe, among other things, the installation, use, maintenance and operation of appropriate safety or other devices or appliances, to establish uniform or other standards of equipment, and to require the performance of any other act which the health or safety of its employees, customers or the public may demand.

(Source: P.A. 84-617; 84-1025.)

(220 ILCS 5/8-505.1)

Sec. 8-505.1. Non-emergency vegetation management activities.

(a) Except as provided in subsections (b), (c), and (d), in conducting its non-emergency vegetation management activities, an electric public utility shall:

(1) Follow the most current tree care and maintenance standard practices set forth in ANSI A300 published by the American National Standards Institute and the most current applicable Occupational Safety and Health Administration regulations regarding worker safety.

(2) Provide direct notice of vegetation management activities no less than 21 days nor more than 90 days before the activities begin.

(A) If the vegetation management activities will occur in an incorporated municipality, the notice must be given to the mayor or his or her designee.

(B) If the vegetation management activities will occur in an unincorporated area, the notice must be given to the chairman of the county board or his or her designee.

(C) Affected customers shall be notified directly.

(D) Affected property owners shall be notified by a published notice in a newspaper or newspapers in general circulation and widely distributed within the entire area in which the vegetation management activities notice will occur.

(E) Circuit maps or a description by common address of the area to be affected by vegetation management activities must accompany any notice to a mayor or his or her designee or to a chairman of a county board or his or her designee.

The electric public utility giving the direct and published notices required in this subsection (a)(2) shall provide notified customers and property owners with (i) a statement of the vegetation management activities planned, (ii) the address of a website and a toll-free telephone number at which a written disclosure of all dispute resolution opportunities and processes, rights, and remedies provided by the electric public utility may be obtained, (iii) a statement that the customer and the property owner may appeal the planned vegetation management activities through the electric public utility and the Illinois Commerce Commission, (iv) a toll-free telephone number through which communication may be had with a representative of the electric public utility regarding the vegetation management activities, and (v) the telephone number of the Consumer Affairs Officer of the Illinois Commerce Commission. The notice shall also include a statement that circuit maps and common addresses of the area to be affected by the vegetation management activities are on file with the office of the mayor of an affected municipality or his or her designee and the office of the county board chairman of an affected county or his or her designee.

The Commission shall have sole authority to investigate, issue, and hear complaints against the utility under this subsection (a).

(b) A public utility shall not be required to comply with the requirements of subsection (d) or of paragraph (2) of subsection (a) when it is taking actions directly related to an emergency to restore reliable service after interruptions of service.

(c) A public utility shall not be required to comply with the requirements of subsection (a) or (d) if there is a franchise, contract, or written agreement between the public utility and the municipality or county mandating specific vegetation management practices. If the franchise, contract, or written agreement between the public utility and the municipality or county establishes requirements for notice to the municipality, county, customers, and property owners, those notice requirements shall control over the notice requirements of paragraph (2) of subsection (a). If the franchise, contract, or written agreement between the public utility and the municipality or county does not establish notice requirements, the notice requirements contained in paragraph (2) of subsection (a) shall control.

(d) If no franchise, contract, or written agreement between a utility and a municipality mandates a specific vegetation management practice and the municipality enacts an ordinance establishing standards for non-emergency vegetation management practices that are contrary to the standards established by this Section and the vegetation management activities of the electric public utility cost substantially more, as a direct consequence, then the electric public utility may, before vegetation management activities begin, apply to the municipality for an agreement to pay the additional cost. When an application for an agreement is made to the municipality, no vegetation management activities shall begin until the municipality responds to the application by agreement or rejection or dispute resolution proceedings are completed. The application shall be supported by a detailed specification of the difference between the standards established by this Section and the contrary standards established by the municipal ordinances and by a good faith bid or proposal obtained from a utility contractor or contractors quantifying the additional cost for performing the specification. When the municipality receives the specification and the utility contractor's bid or proposal, the municipality shall agree, reject, or initiate dispute resolution proceedings regarding the application within 90 days after the application's receipt. If the municipality does not act within 90 days or informs the utility that it will not agree, the electric public utility may proceed and need not comply with the contrary ordinance standard. When there is a dispute regarding (i) the accuracy of the specification, (ii) whether there is a conflict with the standards established by this Section, or (iii) any aspect of the bid or proposal process, the Illinois Commerce Commission shall hear and resolve the disputed matter or matters, with the electric public utility having the burden of proof. A municipality may have a person trained in tree care and maintenance generally monitor and discuss with the vegetation management supervisory personnel of the electric public utility the performance of the public utility's vegetation management activities without any claim for costs hereunder by the public utility arising therefrom.

The provisions of this Section shall not in any way diminish or replace other civil or administrative remedies available to a customer or class of customers or a property owner or class of property owners under this Act. This Section does not alter the jurisdiction of the Illinois Commerce Commission in any manner except to obligate the Commission to investigate, issue, and hear complaints against an electric public utility as provided in subsection (a)(2) and to hear and resolve disputed matters brought to it as provided in this subsection. Vegetation management activities by an electric public utility shall not alter, trespass upon, or limit the rights of any property owner.

(Source: P.A. 97-333, eff. 8-12-11.)

(220 ILCS 5/8-505.5)

Sec. 8-505.5. Work on natural gas regulator or manometer. The Commission shall require, under such rules as it may prescribe, a public utility that is performing work on a natural gas regulator or manometer containing mercury that is used to provide natural gas service to test the immediate area around the regulator or manometer for mercury before and after work is performed using testing instruments of the type approved by the Commission. Copies of the test results, if requested, shall be provided to the occupant or owner of the property upon which the regulator or manometer is located at the time the work is performed. The test results shall be available for inspection by the Commission.

(Source: P.A. 92-71, eff. 7-12-01.)

(220 ILCS 5/8-506) (from Ch. 111 2/3, par. 8-506)

Sec. 8-506. Whenever the Commission, after a hearing had upon its own motion or upon complaint, shall determine that public convenience and necessity require a physical connection for the establishment of a continuous line of communication between any 2 or more public utilities for the conveyance of messages or conversations, the Commission may, by order, require that such connection be made. If such public utilities do not agree upon the division between them of the cost of such physical connection or connections, the Commission shall have authority, after further hearing, to establish such division by supplemental order.

(Source: P.A. 84-617.)

(220 ILCS 5/8-507) (from Ch. 111 2/3, par. 8-507)

Sec. 8-507. Every public utility shall file with the Commission, under such rules and regulations as the Commission may prescribe, a report of every accident occurring to or on its plant, equipment, or other property of such a nature to endanger the safety, health or property of any person. Whenever any accident occasions the loss of life or limb to any person, such public utility shall immediately give notice to the Commission of the fact by the speediest means of communication, whether telephone, electronic notification, or post.

The Commission shall investigate all accidents occurring within this State upon the property of any public utility or directly or indirectly arising from or connected with its maintenance or operation, resulting in loss of life or injury to person or property and requiring, in the judgment of the Commission, investigation by it, and shall have the power to make such order or recommendation with respect thereto as in its judgment may seem just and reasonable. Neither the order or recommendation of the Commission nor any accident report filed with the Commission shall be admitted in evidence in any action for damages based on or arising out of the loss of life, or injury to person or property, in this Section referred to.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/8-508) (from Ch. 111 2/3, par. 8-508)

Sec. 8-508. No public utility shall abandon or discontinue any service or, in the case of an electric utility, make any modification as herein defined, without first having secured the approval of the Commission, except in case of assignment, transfer, lease or sale of the whole or any part of its franchises, licenses, permits, plant, equipment, business, or other property to any political subdivision or municipal corporation of this State. In the case of the assignment, transfer, lease or sale, in whole or in part, of any franchise, license, permit, plant, equipment, business or other property to any political subdivision or municipal corporation of this State, the public utility shall notify the Commission of such transaction. "Modification" as used in this Section means any change of fuel type which would result in an annual net systemwide decreased use of 10% or more of coal mined in Illinois. The Commission shall conduct public hearings on any request by a public utility to make such modification and shall accept testimony from interested parties qualified to provide evidence regarding the cost or cost savings of the proposed modification as compared with the cost or cost savings of alternative actions by the utility and shall consider the impact on employment related to the production of coal in Illinois. Such hearings shall be commenced no later than 30 days after the filing of the request by the public utility and shall be concluded within 120 days from the date of filing. The Commission must issue its final determination within 60 days of the conclusion of the hearing. In making its determination the Commission shall attach primary weight to the cost or cost savings to the customers of the utility. In granting its approval, the Commission may impose such terms, conditions or requirements as in its judgment are necessary to protect the public interest. Provided, however, that any public utility abandoning or discontinuing service in pursuance of authority granted by the Commission shall be deemed to have waived any and all objections to the terms, conditions or requirements imposed by the Commission in that regard. Provided, further, that nothing in this Section shall be construed to limit the right of a public utility to discontinue service to individual patrons in accordance with the effective rules, regulations, and practices of such public utility.

The Commission, after a hearing upon its own motion or upon petition of any public utility, shall have power by order to authorize or require any public utility to curtail or discontinue service to individual customers or classes thereof, or for specific purposes or uses, and otherwise to regulate the furnishing of service, provided that preference for service shall be given to those customers serving essential human needs and governmental agencies performing law enforcement functions, whenever and to the extent such action is required by the convenience and necessity of the public during time of war, invasion, insurrection or martial law, or by reason of a catastrophe, emergency, or shortage of fuel, supplies or equipment employed or service furnished by such public utility; provided, however, that an interim order, effective for a period not exceeding 45 days, may be made without a hearing if the circumstances do not reasonably permit the holding of a hearing. Orders for the curtailment or discontinuance of service pursuant to this paragraph shall not be continued in effect for any period beyond that which is reasonably necessary, shall be vacated by the Commission as soon as public convenience and necessity permit, and shall include such arrangements for substitute service in the interim as the Commission in its judgment may impose. Every such order, during the period it is in effect and for such further period, if any, as the Commission may provide, shall have the effect of suspending the operation of all prior orders or parts of orders of the Commission inconsistent therewith. No public utility shall be held liable for any damage resulting from any action taken, or any omission to act, pursuant to or in compliance with any order under this paragraph for the curtailment or discontinuance of service unless such order was procured by the fraud of the public utility.

(Source: P.A. 102-457, eff. 1-1-22.)

(220 ILCS 5/8-508.1) (from Ch. 111 2/3, par. 8-508.1)

Sec. 8-508.1. (a) As used in this Section:

(1) "Decommissioning" means the series of activities undertaken at the time a nuclear power plant is permanently retired from service to ensure that the final entombment, decontamination, dismantlement, removal and disposal of the plant, including the plant site, and of any radioactive components and materials associated with the plant, is accomplished in compliance with all applicable Illinois and federal laws, and to ensure that such final disposition does not pose any threat to the public health and safety.

(2) "Decommissioning costs" means all reasonable costs and expenses incurred in connection with the entombment, decontamination, dismantlement, removal and disposal of the structures, systems and components of a nuclear power plant at the time of decommissioning, including all expenses to be incurred in connection with the preparation for decommissioning, such as engineering and other planning expenses, and to be incurred after the actual decommissioning occurs, such as physical security and radiation monitoring expenses, less proceeds of insurance, salvage or resale of machinery, construction equipment or apparatus the cost of which was charged as a decommissioning expense.

(3) "Decommissioning trust" or "trust" means a fiduciary account in a bank or other financial institution established to hold the decommissioning funds provided pursuant to subsection (b)(2) of this Section for the eventual purpose of paying decommissioning costs, which shall be separate from all other accounts and assets of the public utility establishing the trust.

(4) "Nuclear power plant" or "plant" means a nuclear fission thermal power plant. Each unit of a multi-unit site shall be considered a separate plant.

(b) By 90 days after the effective date of this amendatory Act of 1988, or by the date that the unit satisfies the criteria used by the Internal Revenue Service for determining when depreciation commences for federal income tax purposes on a new generating unit, whichever is later, every public utility that owns or operates, in whole or in part, a nuclear power plant shall:

(1) establish 2 decommissioning trusts, which shall be a "tax qualified" decommissioning trust and a "non-tax qualified" decommissioning trust and shall hold the decommissioning funds established by the public utility for all nuclear power plants pursuant to subsection (b)(2) of this Section;

(2) establish 2 decommissioning funds for each such plant, each of which shall be held for a plant as a separate account in a decommissioning trust; and

(3) designate an independent trustee, subject to the approval of the Commission, to administer each of the decommissioning trusts.

(c) The 2 decommissioning trusts shall be known as the "tax qualified" decommissioning trust and the "non-tax qualified" decommissioning trust respectively. Each trust shall be established and maintained as follows:

(1) The "tax qualified" trust shall be established and maintained in accordance with Section 468A of the Internal Revenue Code of 1986 or any successor thereto and shall be funded by the public utility for each such power plant through annual payments by the public utility that shall not exceed the maximum amount allowable as a deduction for federal income tax purposes for the year for which the payments were made, in accordance with Section 468A of the Internal Revenue Code of 1986 or any successor thereto.

(2) The "non-tax qualified" decommissioning trust shall be funded by the public utility for each such power plant through annual payments by the public utility that shall consist of the difference between the total amounts of decommissioning expenses collected after the effective date of this amendatory Act of 1988 through rates and charges from the public utility's customers as provided by the Commission minus the amounts contributed to the "tax qualified" trust as provided by subsection (c)(1) of this Section and deductible for federal income tax purposes in accordance with Section 468A of the Internal Revenue Code of 1986 or any successor thereto.

(3) The following restrictions shall apply in regard to administration of each decommissioning trust:

(i) Distributions may be made from a nuclear decommissioning trust only to satisfy the liabilities of the public utility for nuclear decommissioning costs relating to the nuclear power plant for which the decommissioning fund was established and to pay administrative costs, income taxes and other incidental expenses of the trust.

(ii) Any assets in a nuclear decommissioning trust that exceed the amount necessary to pay the nuclear decommissioning costs of the nuclear power plant for which the decommissioning fund was established shall be refunded to the public utility that established the fund for the purpose of refunds or credits, as soon as practicable, to the utility's customers.

(iii) In the event a public utility sells or otherwise disposes of its direct ownership interest, or any part thereof, in a nuclear power plant with respect to which a nuclear decommissioning fund has been established, the assets of the fund shall be distributed to the public utility to the extent of the reductions in its liability for future decommissioning after taking into account the liabilities of the public utility for future decommissioning of such nuclear power plant and the liabilities that have been assumed by another entity. The public utility shall, as soon as practicable, provide refunds or credits to its customers representing the full amount of the reductions in its liability for future decommissioning.

(iv) The trustee shall invest the "tax qualified" trust assets only in secure assets that are prudent investments for assets held in trust and in such a way as to attempt to maximize the after-tax return on funds invested, subject to the limitations specified in Section 468A of the Internal Revenue Code of 1986 or any successor thereto.

(v) The trustee shall invest the "non-tax qualified" trust assets only in secure assets that are prudent investments for assets held in trust and in such a way as to attempt to maximize the after-tax return on funds invested. However the trustee shall not invest any portion of the "non-tax qualified" trust's funds in the securities or assets of any operator of a nuclear power plant.

(vi) The "non-tax qualified" trust shall be subject to the prohibitions against self-dealing applicable to the "tax qualified" trust as specified in Section 468A of the Internal Revenue Code of 1986, or any successor thereto.

(vii) All income earned by the trust's funds shall become a part of the trust's funds and subject to the provisions of this Section.

(viii) The Commission may adopt by rule or regulation such further restrictions as it deems necessary for the sound management of the trust's funds, consistent with the purposes of this Section.

(d) By 90 days after the effective date of this amendatory Act of 1988, the Commission shall determine an appropriate method to segregate, either internally or externally, all decommissioning funds collected prior to the effective date of this amendatory Act of 1988 by the utility from its customers, and shall order any change in past decommissioning funding methods that the Commission finds necessary. In making its determination of the appropriate funding method, the Commission shall give consideration to, but not be limited by, all applicable federal regulations. The change in funding method shall be phased-in over an appropriate period of time.

(e) The trustee of a trust shall report annually to the Commission, or more frequently if ordered by the Commission. The report shall include:

(1) the trust's State and federal tax returns;

(2) a report on the trust's portfolio of investments and the return thereon;

(3) the date and amount of payments received by the trust from the public utility;

(4) a copy of all correspondence between the trust and the Internal Revenue Service; and

(5) any other information the Commission orders the trust to provide.

(f) A nuclear decommissioning trust established pursuant to this Section shall be exempt from taxation in Illinois.

(g) Beginning on or before May 1, 2020, and every 2 years thereafter, the owner or operator of each nuclear power plant in this State shall provide the Commission with a copy of the nuclear decommissioning funding assurance status report submitted to the Nuclear Regulatory Commission and, as applicable, to the Federal Energy Regulatory Commission. Beginning June 1, 2020, and every 2 years thereafter, the Commission shall provide the General Assembly with a copy of the nuclear decommissioning funding assurance status report for shutdown units as submitted by the owner or operator of a nuclear power plant in this State to the Nuclear Regulatory Commission and, as applicable, to the Federal Energy Regulatory Commission.

(Source: P.A. 101-44, eff. 1-1-20.)

(220 ILCS 5/8-509) (from Ch. 111 2/3, par. 8-509)

Sec. 8-509. When necessary for the construction of any alterations, additions, extensions or improvements ordered or authorized under Section 8-406.1 or 8-503 of this Act, any public utility may enter upon, take or damage private property in the manner provided for by the law of eminent domain. If a public utility seeks relief under this Section in the same proceeding in which it seeks a certificate of public convenience and necessity under Section 8-406.1 of this Act, the Commission shall enter its order under this Section either as part of the Section 8-406.1 order or at the same time it enters the Section 8-406.1 order. If a public utility seeks relief under this Section after the Commission enters its order in the Section 8-406.1 proceeding, the Commission shall issue its order under this Section within 45 days after the utility files its petition under this Section.

This Section applies to the exercise of eminent domain powers by telephone companies or telecommunications carriers only when the facilities to be constructed are intended to be used in whole or in part for providing one or more intrastate telecommunications services classified as "noncompetitive" under Section 13-502 in a tariff filed by the condemnor. The exercise of eminent domain powers by telephone companies or telecommunications carriers in all other cases shall be governed solely by "An Act relating to the powers, duties and property of telephone companies", approved May 16, 1903, as now or hereafter amended.

This Section applies to the exercise of eminent domain powers by an owner or operator of a pipeline designed, constructed, and operated to transport carbon dioxide to which the Commission has granted a certificate under Section 20 of the Carbon Dioxide Transportation and Sequestration Act and may seek eminent domain authority from the Commission under this Section. If the applicant of such a certificate of authority for a new carbon dioxide pipeline seeks relief under this Section in the same proceeding in which it seeks a certificate of authority for a new carbon dioxide pipeline under Section 20 of the Carbon Dioxide Transportation and Sequestration Act, the Commission shall enter its order under this Section either as part of or at the same time as its order under the Carbon Dioxide Transportation and Sequestration Act. Notwithstanding anything to the contrary in this Section, the owner or operator of such a pipeline shall not be considered to be a public utility for any other provisions of this Act.

(Source: P.A. 103-651, eff. 7-18-24.)

(220 ILCS 5/8-509.5)

Sec. 8-509.5. Eminent domain. Notwithstanding any other provision of this Act, any power granted under this Act to acquire property by condemnation or eminent domain is subject to, and shall be exercised in accordance with, the Eminent Domain Act.

(Source: P.A. 94-1055, eff. 1-1-07.)

(220 ILCS 5/8-510) (from Ch. 111 2/3, par. 8-510)

Sec. 8-510. Land surveys and land use studies. For the purpose of making land surveys and land use studies, any public utility that has been granted a certificate of public convenience and necessity by, or received an order under Section 8-503 or 8-406.1 of this Act from, the Commission may, 30 days after providing written notice to the owner thereof by registered mail and after providing a second notice to the owner of record, as identified in the records of the relevant county tax assessor, by telephone or electronic mail or by registered mail in the event the property owner has not been notified by other means, at least 3 days, but not more than 15 days, prior to the stated date in the notice, identifying the date when land surveys and land use studies will first begin on their property and informing the landowner that they or their agent may be present when the land surveys or land use studies occur, enter upon the property of any owner who has refused permission for entrance upon that property, but subject to responsibility for all damages which may be inflicted thereby.

(Source: P.A. 99-399, eff. 8-18-15.)

(220 ILCS 5/8-511)

Sec. 8-511. (Repealed).

(Source: P.A. 96-37, eff. 7-13-09. Repealed by P.A. 96-40, eff. 7-13-09.)

(220 ILCS 5/8-512)

Sec. 8-512. Renewable energy access plan.

(a) It is the policy of this State to promote cost-effective transmission system development that ensures reliability of the electric transmission system, lowers carbon emissions, minimizes long-term costs for consumers, and supports the electric policy goals of this State. The General Assembly finds that:

(1) Transmission planning, primarily for reliability purposes, but also for economic and public policy reasons is conducted by regional transmission organizations in which transmission-owning Illinois utilities and other stakeholders are members.

(2) Order No. 1000 of the Federal Energy Regulatory Commission requires regional transmission organizations to plan for transmission system needs in light of State public policies and to accept input from states during the transmission system planning processes.

(3) The State of Illinois does not currently have a comprehensive power and environmental policy planning process to identify transmission infrastructure needs that can serve as a vital input into the regional and interregional transmission organization planning processes conducted under Order No. 1000 and other laws and regulations.

(4) This State is an electricity generation and power transmission hub, and can leverage that position to invest in infrastructure that enables new and existing Illinois generators to meet the public policy goals of the State of Illinois and of interconnected states while cost-effectively supporting tens of thousands of jobs in the renewable energy sector in this State.

(5) The nation has a need to readily access this State's low-cost, clean electric power, and this State also desires access to clean energy resources in other states to develop and support its low-carbon economy and keep electricity prices low in Illinois and interconnected States.

(6) Existing transmission infrastructure may constrain the State's achievement of 100% renewable energy by 2050, the accelerated adoption of electric vehicles in a just and equitable way, and electrification of additional sectors of the Illinois economy.

(7) Transmission system congestion within this State and the regional transmission organizations serving this State limits the ability of this State's existing and new electric generation facilities that do not emit carbon dioxide, including renewable energy resources and zero emission facilities, to serve the public policy goals of this State and other states, which constrains investment in this State.

(8) Investment in infrastructure to support existing and new electric generation facilities that do not emit carbon dioxide, including renewable energy resources and zero emission facilities, stimulates significant economic development and job growth in this State, as well as creates environmental and public health benefits in this State.

(9) Creating a forward-looking plan for this State's electric transmission infrastructure, as opposed to relying on case-by-case development and repeated marginal upgrades, will achieve a lower-cost system for Illinois' electricity customers. A forward-looking plan can also help integrate and achieve a comprehensive set of objectives and multiple state, regional, and national policy goals.

(10) Alternatives to overhead electric transmission lines can achieve cost-effective resolution of system impacts and warrant investigation of the circumstances under which those alternatives should be considered and approved. The alternatives are likely to be beneficial as investment in electric transmission infrastructure moves forward.

(11) Because transmission planning is conducted primarily by the regional transmission organizations, the Commission should be advocating for the State's interests at the regional transmission organizations to ensure that such planning facilitates the State's policies and goals, including overall consumer savings, power system reliability, economic development, environmental improvement, and carbon reduction.

(b) Consistent with the findings identified in subsection (a), the Commission shall open an investigation to develop and adopt a renewable energy access plan no later than December 31, 2022. To assist and support the Commission in the development of the plan, the Commission shall retain the services of technical and policy experts with relevant fields of expertise, solicit technical and policy analysis from the public, and provide for a 120-day open public comment period after publication of a draft report, which shall be published no later than 90 days after the comment period ends. The plan shall, at a minimum, do the following:

(1) designate renewable energy access plan zones throughout this State in areas in which renewable energy resources and suitable land areas are sufficient for developing generating capacity from renewable energy technologies;

(2) develop a plan to achieve transmission capacity necessary to deliver the electric output from renewable energy technologies in the renewable energy access plan zones to customers in Illinois and other states in a manner that is most beneficial and cost-effective to customers;

(3) use this State's position as an electricity generation and power transmission hub to create new investment in this State's renewable energy resources;

(4) consider programs, policies, and electric transmission projects that can be adopted within this State that promote the cost-effective delivery of power from renewable energy resources interconnected to the bulk electric system to meet the renewable portfolio standard targets under subsection (c) of Section 1-75 of the Illinois Power Agency Act;

(5) consider proposals to improve regional transmission organizations' regional and interregional system planning processes, especially proposals that reduce costs and emissions, create jobs, and increase State and regional power system reliability to prevent high-cost outages that can endanger lives, and analyze of how those proposals would improve reliability and cost-effective delivery of electricity in Illinois and the region;

(6) make findings and policy recommendations based on technical and policy analysis regarding locations of renewable energy access plan zones and the transmission system developments needed to cost-effectively achieve the public policy goals identified herein;

(6.5) make findings and policy recommendations based on analysis regarding the impact of converting non-powered dams to hydropower dams relative to the alternative renewable energy resources; and

(7) present the Commission's conclusions and proposed recommendations based on its analysis and use the findings and policy recommendations to determine actions that the Commission should take.

(c) No later than December 31, 2025, and every other year thereafter, the Commission shall open an investigation to develop and adopt an updated renewable energy access plan that, at a minimum, evaluates the implementation and effectiveness of the renewable energy access plan, recommends improvements to the renewable energy access plan, and provides changes to transmission capacity necessary to deliver electric output from the renewable energy access plan zones.

(Source: P.A. 102-662, eff. 9-15-21; 103-380, eff. 1-1-24.)

(220 ILCS 5/Art. IX heading) ARTICLE IX. RATES

(220 ILCS 5/9-101) (from Ch. 111 2/3, par. 9-101)

Sec. 9-101. All rates or other charges made, demanded or received by any product or commodity furnished or to be furnished or for any service rendered or to be rendered shall be just and reasonable. Every unjust or unreasonable charge made, demanded or received for such product or commodity or service is hereby prohibited and declared unlawful. All rules and regulations made by a public utility affecting or pertaining to its charges to the public shall be just and reasonable.

(Source: P.A. 84-617.)

(220 ILCS 5/9-102) (from Ch. 111 2/3, par. 9-102)

Sec. 9-102. Every public utility shall file with the Commission and shall print and keep open to public inspection schedules showing all rates and other charges, and classifications, which are in force at the time for any product or commodity furnished or to be furnished by it, or for any service performed by it, or for any service in connection therewith, or performed by any public utility controlled or operated by it. Every public utility shall file with and as a part of such schedule and shall state separately all rules, regulations, storage or other charges, privileges and contracts that in any manner affect the rates charged or to be charged for any service. Such schedule shall be filed for all services performed wholly or partly within this State, and the rates and other charges and classifications shall not, without the consent of the Commission, exceed those in effect on December 31, 1985. But nothing in this section shall prevent the Commission from approving or fixing rates or other charges or classifications from time to time, in excess of or less than those shown by said schedules.

Where a schedule of joint rates or other charges, or classifications is or may be in force between two or more public utilities such schedules shall in like manner be printed and filed with the Commission, and so much thereof as the Commission shall deem necessary for the use of the public shall be filed in every office of such public utility in accordance with the terms of Section 9-103 of this Act. Unless otherwise ordered by the Commission a schedule showing such joint rates or other charges, or classifications need not be filed with the Commission by more than one of the parties to it: Provided, that there is also filed with the Commission a concurrence in such schedule by each of the other parties thereto.

Every public utility shall file with the Commission copies of all contracts, agreements or arrangements with other public utilities, in relation to any service, product or commodity affected by the provisions of this Act, to which it may be a party, and copies of all other contracts, agreements or arrangements with any other person or corporation affecting in the judgment of the Commission the cost to such public utility of any service, product or commodity.

(Source: P.A. 84-617; 84-1025.)

(220 ILCS 5/9-102.1)

Sec. 9-102.1. Negotiated rates.

(a) Notwithstanding anything to the contrary in any other Section of Article IX of this Act, the Commission may approve one or more rate schedules filed by a public utility that enable the public utility to provide service to customers under contracts that are treated as proprietary and confidential by the Commission notwithstanding the filing thereof. Service under the contracts shall be provided on such terms and for such rates or charges as the public utility and the customer agree upon, without regard to any rate schedules the public utility may have filed with the Commission under any other Section of Article IX of this Act. The contracts shall be filed with the Commission, notwithstanding anything to the contrary in any schedule referred to in subsection (b) of this Section. For purposes of Section 3-121 of this Act, the amounts collected under the contracts shall be treated as having been collected under rates that the public utility is required to file under Section 9-102 of this Act.

(b) Each schedule described in subsection (a) that became effective before August 25, 1995, and any contract thereunder, shall be deemed to have become effective in accordance with its terms, subject to the provisions of any Commission order that purported to authorize the schedule.

(c) In any determination of the rates to be charged by an electric public utility having contracts in effect pursuant to schedules filed under this Section or schedules referred to in subsection (b) of this Section, the revenues received, or to be received, by the electric public utility under each such contract shall be deemed to be equal to the revenues, based on the actual usage of the customer, that would have been, or would be, received under the lowest rates available under schedules on file pursuant to Section 9-201, applicable to a class of consumers that includes the customer, including any applicable riders or surcharges, plus any revenues that would have been, or would be required to pay for investment or expenses incurred by the electric public utility that would not be incurred if service were provided under such lowest rates. The cost of capital used to determine rates to be charged by the electric public utility shall be that which would have obtained if service were provided under such lowest rates. The provisions of this subsection (c) shall not apply: (1) in any determination of the rates to be charged by a gas public utility, and (2) in any determination of the rates to be charged by an electric public utility, to contracts in effect prior to the effective date of this amendatory Act of 1996 pursuant to economic development schedules referred to in Section 9-241 of this Act, under which the electric public utility is authorized to provide discounts for new electrical sales that result from the location of new or expanded industrial facilities in the electric public utility's service territory. The preceding sentence shall not be construed to diminish the Commission's existing authority as of the effective date of this amendatory Act of 1996 to allocate the costs of all public utilities equitably, in any determination of rates, so as to set rates which are just and reasonable.

(d) Any contract filed pursuant to the provisions of subsection (a) of this Section shall be accorded proprietary and confidential treatment by the Commission and otherwise deemed to be exempt from the requirements of Sections 9-102, 9-103, 9-104, 9-201, 9-240, 9-241, and 9-243, except to the extent the Commission may, in its discretion, order otherwise. The Commission shall permit any statutory consumer protection agency to have access to any such contract, provided that: (i) the agency, and each individual that will have access on behalf of the agency, agree in writing to keep such contract confidential, such agreement to be in a form established by the Commission; and (ii) access is limited to full-time employees of the agency and such other persons as are acceptable to the public utility or, if the agency and the public utility are unable to agree, are determined to be acceptable by the Commission. "Statutory consumer protection agency" means any office, corporation, or other agency created by any Illinois statute as of the effective date of this amendatory Act of 1996 that has an express statutory duty to represent the interest of public utility customers, any such agency subsequently created by act of the General Assembly that expressly authorizes the agency to access the information described in this subsection, or the Attorney General of the State of Illinois.

(e) Nothing in this Section shall be construed to give a public utility the authority to provide electric or natural gas service to a customer the public utility is not otherwise lawfully entitled to serve. Nothing in this Section shall be construed to affect in any way the service rights of electric suppliers as granted under the Electric Supplier Act.

(f) The provisions of subsection (b) of this Section 9-102.1 are intended to be severable from the remaining provisions of this Act; and therefore, no determination of the validity of the provisions of subsection (b) shall affect the validity of the remaining provisions of this Section 9-102.1.

(g) After January 1, 2001, no contract for electric service may be entered into under any schedule filed pursuant to the provisions of subsection (a) of this Section or under any schedule referred to in subsection (b) of this Section. The foregoing provision shall not affect any contract entered into prior to January 1, 2001.

(h) Nothing contained in this Section shall be construed as preventing any customer or other appropriate party from filing a complaint or otherwise requesting that the Commission investigate the reasonableness of the terms and conditions of any schedule filed under this Section or referred to in subsection (b) of this Section. Nothing contained in this Section shall be construed as affecting the right of any customer or public utility to enter into and enforce any contract providing for the amounts to be charged for service where the contract is or has been filed pursuant to any other Section of this Act. Nothing contained in this Section shall be construed to limit any Commission authority to authorize a public utility to engage in experimental programs relating to competition, including direct access programs.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/9-103) (from Ch. 111 2/3, par. 9-103)

Sec. 9-103. Posting of rate schedules. Subject to such rules and regulations as the Commission may prescribe, the schedules referred to in Section 9-102 shall be posted or kept on file in every office of a public utility where the public transacts business with such public utility. Any or all of such schedules kept as aforesaid shall be immediately produced by such public utility for inspection upon the demand of any person. A notice printed in bold type, in size prescribed by the Commission, stating that such schedules are on file with the agent and open to inspection by any person, and that the agent will assist any person to determine from such schedules any rates or other charges, classification, rules or regulations in force, shall be kept posted by the public utility in two public and conspicuous places in every such office. The form of every such schedule shall be prescribed by the Commission: Provided, that in lieu of filing the entire schedule in each office, any public utility may, subject to the regulations of the Commission, file or keep posted at such office, schedules of such rates or other charges, classifications, rules and regulations relating thereto, as are applicable at, to and from the place where such office is located.

The Commission may determine and prescribe the form in which the schedules required by this Act to be filed with the Commission and to be kept open to public inspection shall be prepared and arranged, and may change the form from time to time if it shall be found expedient.

(Source: P.A. 91-341, eff. 7-29-99.)

(220 ILCS 5/9-104) (from Ch. 111 2/3, par. 9-104)

Sec. 9-104. No public utility shall undertake to perform any service or to furnish any product or commodity unless or until the rates and other charges and classifications, rules and regulations relating thereto, applicable to such service, product or commodity, have been filed and published in accordance with the provisions of this Act: Provided, that in cases of emergency, a service, product or commodity not specifically covered by the schedules filed, may be performed or furnished at a reasonable rate, which rate shall forthwith be filed and shall be subject to review in accordance with the provisions of this Act.

(Source: P.A. 84-617.)

(220 ILCS 5/9-107)

Sec. 9-107. Revenue balancing adjustments.

(a) In this Section:

"Reconciliation period" means a period beginning with the January monthly billing period and extending through the December monthly billing period.

"Rate case reconciliation revenue requirement" means the final distribution revenue requirement or requirements approved by the Commission in the utility's rate case or formula rate proceeding to set the rates initially applicable in the relevant reconciliation period after the conclusion of the period. In the event the Commission has approved more than one revenue requirement for the reconciliation period, the amount of rate case revenue under each approved revenue requirement shall be prorated based upon the number of days under which each revenue requirement was in effect.

(b) If an electric utility has a performance-based formula rate in effect under Section 16-108.5, then the utility shall be permitted to revise the formula rate and schedules to reduce the 50 basis point values to zero that would otherwise apply under paragraph (5) of subsection (c) of Section 16-108.5. Such revision and reduction shall apply beginning with the reconciliation conducted for the 2017 calendar year.

If the utility no longer has a performance-based formula in effect under Section 16-108.5, then the utility shall be permitted to implement the revenue balancing adjustment tariff described in subsection (c) of this Section.

(c) An electric utility that is authorized under subsection (b) of this Section to implement a revenue balancing adjustment tariff may file the tariff for the purpose of preventing undercollections or overcollections of distribution revenues as compared to the revenue requirement or requirements approved by the Commission on which the rates giving rise to those revenues were based. The tariff shall calculate an annual adjustment that reflects any difference between the actual delivery service revenue billed for services provided during the relevant reconciliation period and the rate case reconciliation revenue requirement for the relevant reconciliation period and shall set forth the reconciliation categories or classes, or a combination of both, in a manner determined at the utility's discretion.

(d) A utility that elects to file the tariff authorized by this Section shall file the tariff outside the context of a general rate case or formula rate proceeding, and the Commission shall, after notice and hearing, approve the tariff or approve with modification no later than 120 days after the utility files the tariff, and the tariff shall remain in effect at the discretion of the utility. The tariff shall also require that the electric utility submit an annual revenue balancing reconciliation report to the Commission reflecting the difference between the actual delivery service revenue and rate case revenue for the applicable reconciliation and identifying the charges or credits to be applied thereafter. The annual revenue balancing reconciliation report shall be filed with the Commission no later than March 20 of the year following a reconciliation period. The Commission may initiate a review of the revenue balancing reconciliation report each year to determine if any subsequent adjustment is necessary to align actual delivery service revenue and rate case revenue. In the event the Commission elects to initiate such review, the Commission shall, after notice and hearing, enter an order approving, or approving as modified, such revenue balancing reconciliation report no later than 120 days after the utility files its report with the Commission. If the Commission does not initiate such review, the revenue balancing reconciliation report and the identified charges or credits shall be deemed accepted and approved 120 days after the utility files the report and shall not be subject to review in any other proceeding.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/9-201) (from Ch. 111 2/3, par. 9-201)

Sec. 9-201. (a) Unless the Commission otherwise orders, and except as otherwise provided in this Section, no change shall be made by any public utility in any rate or other charge or classification, or in any rule, regulation, practice or contract relating to or affecting any rate or other charge, classification or service, or in any privilege or facility, except after 45 days' notice to the Commission and to the public as herein provided. Such notice shall be given by filing with the Commission and keeping open for public inspection new schedules or supplements stating plainly the change or changes to be made in the schedule or schedules then in force, and the time when the change or changes will go into effect, and by publication in a newspaper of general circulation or such other notice to persons affected by such change as may be prescribed by rule of the Commission. The Commission, for good cause shown, may allow changes without requiring the 45 days' notice herein provided for, by an order specifying the changes so to be made and the time when they shall take effect and the manner in which they shall be filed and published.

When any change is proposed in any rate or other charge, or classification, or in any rule, regulation, practice, or contract relating to or affecting any rate or other charge, classification or service, or in any privilege or facility, such proposed change shall be plainly indicated on the new schedule filed with the Commission, by some character to be designated by the Commission, immediately preceding or following the item.

When any public utility providing water or sewer service proposes any change in any rate or other charge, or classification, or in any rule, regulation, practice, or contract relating to or affecting any rate or other charge, classification or service, or in any privilege or facility, such utility shall, in addition to the other notice requirements of this Act, provide notice of such change to all customers potentially affected by including a notice and description of such change, and of Commission procedures for intervention, in the first bill sent to each such customer after the filing of the proposed change.

For water or sewer utilities with greater than 15,000 total customers, the following notice requirements are applicable, in addition to the other notice requirements of this Act:

(1) As a separate bill insert, an initial notice in the first bill sent to all customers potentially affected by the proposed change after the filing of the proposed change shall include:

(A) the approximate date when the change or changes shall go into effect assuming the Commission utilizes the 11-month process as described in this Section;

(B) a statement indicating that the estimated bill impact may vary based on multiple factors, including, but not limited to, meter size, usage volume, and the fire protection district;

(C) the water or sewer utility's customer service number or other number as may be appropriate where an authorized agent of the water or sewer utility can explain how the proposed increase might impact an individual customer's bill;

(D) if the proposed change involves a change from a flat to a volumetric rate, an explanation of volumetric rate;

(E) a reference to the water or sewer utility's website where customers can find tips on water conservation; and

(F) for customers receiving both water and sewer service from a utility and if the customer has an option to install a separate meter for irrigation to mitigate sewer charges, an explanation of the water and sewer utility's and the customer's responsibilities for installation of a separate meter if such a change is approved.

(2) A second notice to all customers shall be included on the first bill after the Commission suspends the tariffs initiating the rate case.

(3) Final notice of such change shall be sent to all customers potentially affected by the proposed change by including information required under this paragraph (3) with the first bill after the effective date of the rates approved by the Final Order of the Commission in a rate case. The notice shall include the following:

(A) the date when the change or changes went into effect;

(B) the water or sewer utility's customer service number or other number as may be appropriate where an authorized agent of the water or sewer utility can explain how the proposed increase might impact an individual customer's bill;

(C) an explanation that usage shall now be charged at a volumetric rate rather than a flat rate, if applicable;

(D) a reference to the water or sewer utility's website where the customer can find tips on water conservation; and

(E) for customers receiving both water and sewer service from a utility and if the customer has an option to install a separate meter for irrigation to mitigate sewer charges, an explanation of the water and sewer utility's and the customer's responsibilities for installation of a separate meter if such a change is approved.

(b) Whenever there shall be filed with the Commission any schedule stating an individual or joint rate or other charge, classification, contract, practice, rule or regulation, the Commission shall have power, and it is hereby given authority, either upon complaint or upon its own initiative without complaint, at once, and if it so orders, without answer or other formal pleadings by the interested public utility or utilities, but upon reasonable notice, to enter upon a hearing concerning the propriety of such rate or other charge, classification, contract, practice, rule or regulation, and pending the hearing and decision thereon, such rate or other charge, classification, contract, practice, rule or regulation shall not go into effect. The period of suspension of such rate or other charge, classification, contract, practice, rule or regulation shall not extend more than 105 days beyond the time when such rate or other charge, classification, contract, practice, rule or regulation would otherwise go into effect unless the Commission, in its discretion, extends the period of suspension for a further period not exceeding 6 months.

All rates or other charges, classifications, contracts, practices, rules or regulations not so suspended shall, on the expiration of 45 days from the time of filing the same with the Commission, or of such lesser time as the Commission may grant, go into effect and be the established and effective rates or other charges, classifications, contracts, practices, rules and regulations, subject to the power of the Commission, after a hearing had on its own motion or upon complaint, as herein provided, to alter or modify the same.

Within 30 days after such changes have been authorized by the Commission, copies of the new or revised schedules shall be posted or filed in accordance with the terms of Section 9-103 of this Act, in such a manner that all changes shall be plainly indicated. The Commission shall incorporate into the period of suspension a review period of 4 business days during which the Commission may review and determine whether the new or revised schedules comply with the Commission's decision approving a change to the public utility's rates. Such review period shall not extend the suspension period by more than 2 days. Absent notification to the contrary within the 4 business day period, the new or revised schedules shall be deemed approved.

(c) If the Commission enters upon a hearing concerning the propriety of any proposed rate or other charge, classification, contract, practice, rule or regulation, the Commission shall establish the rates or other charges, classifications, contracts, practices, rules or regulations proposed, in whole or in part, or others in lieu thereof, which it shall find to be just and reasonable. In such hearing, the burden of proof to establish the justness and reasonableness of the proposed rates or other charges, classifications, contracts, practices, rules or regulations, in whole and in part, shall be upon the utility. The utility, the staff of the Commission, the Attorney General, or any party to a proceeding initiated under this Section who has been granted intervenor status and submitted a post-hearing brief must be given the opportunity to present oral argument, if requested no later than the date for filing exceptions, on the propriety of any proposed rate or other charge, classification, contract, practice, rule, or regulation. No rate or other charge, classification, contract, practice, rule or regulation shall be found just and reasonable unless it is consistent with Sections of this Article.

(d) Except where compliance with Section 8-401 of this Act is of urgent and immediate concern, no representative of a public utility may discuss with a commissioner, commissioner's assistant, or administrative law judge in a non-public setting a planned filing for a general rate increase. If a public utility makes a filing under this Section, then no substantive communication by any such person with a commissioner, commissioner's assistant, or administrative law judge concerning the filing is permitted until a notice of hearing has been issued. After the notice of hearing has been issued, the only communications by any such person with a commissioner, commissioner's assistant, or administrative law judge concerning the filing permitted are communications permitted under Section 10-103 of this Act. If any such communication does occur, then within 5 days of the docket being initiated all details relating to the communication shall be placed on the public record of the proceeding. The record shall include any materials, whether written, recorded, filmed, or graphic in nature, produced or reproduced on any media, used in connection with the communication. The record shall reflect the names of all persons who transmitted, received, or were otherwise involved in the communication, the duration of the communication, and whether the communication occurred in person or by other means. In the case of an oral communication, the record shall also reflect the location or locations of all persons involved in the communication and, if the communication occurred by telephone, the telephone numbers for the callers and recipients of the communication. A commissioner, commissioner's assistant, or administrative law judge who is involved in any such communication shall be recused from the affected proceeding. The Commission, or any commissioner or administrative law judge presiding over the proceeding shall, in the event of a violation of this Section, take action necessary to ensure that such violation does not prejudice any party or adversely affect the fairness of the proceedings including dismissing the affected proceeding. Nothing in this subsection (d) is intended to preclude otherwise allowable updates on issues that may be indirectly related to a general rate case filing because cost recovery for the underlying activity may be requested. Such updates may include, without limitation, issues related to outages and restoration, credit ratings, security issuances, reliability, Federal Energy Regulatory Commission matters, Federal Communications Commission matters, regional reliability organizations, consumer education, or labor matters, provided that such updates may not include cost recovery in a planned rate case.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/9-201.5)

Sec. 9-201.5. Decommissioning nuclear power plants; rates.

(a) The Commission may after hearing, in a rate case or otherwise, authorize the institution of rate provisions or tariffs that increase or decrease charges to customers to reflect changes in, or additional or reduced costs of, decommissioning nuclear power plants, including accruals for estimates of those costs, irrespective of any changes in other costs or revenues; provided the revenues collected under such rates or tariffs are used to recover costs associated with contributions to appropriate decommissioning trust funds or to reduce the amounts to be charged under such rates or tariffs in the future. These provisions or tariffs shall hereinafter be referred to as "decommissioning rates".

(b) A public utility that does not have a decommissioning rate in effect on the effective date of this amendatory Act of 1994 may not place a decommissioning rate in effect before January 1, 1995. Changes in charges under a decommissioning rate shall not be subject to the notice and filing requirements of subsection (a) of Section 9-201 of this Act, but a decommissioning rate of a utility that does not have such a rate in effect before the effective date of this amendatory Act of 1994 shall provide that no increase in charges under that rate may take effect until 60 days after the utility provides the proposed increased charge to the Commission for review. The Commission may require that a decommissioning rate contain provisions for reconciling amounts collected under the rate with both reasonably projected costs and actual costs prudently incurred. As used in this Section, "decommissioning costs" and "decommissioning trust fund" have the same meaning as in Section 8-508.1 of this Act.

(c) Nothing contained in this amendatory Act of 1994 shall affect any determination of the authority of the Commission before the effective date of this amendatory Act of 1994. Nothing contained in this amendatory Act of 1994 shall be used in any determination of the authority of the Commission after the effective date of this amendatory Act of 1994, except with respect to decommissioning rates.

(d) A decommissioning rate authorized by the Commission under this Section and the decommissioning cost studies underlying the rate shall be subject to hearing and review, in a rate case or otherwise, not less than once every 6 years.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/9-202) (from Ch. 111 2/3, par. 9-202)

Sec. 9-202. (a) Whenever the Commission is of the opinion and so finds after an examination of any report or reports, annual or otherwise, filed with the Commission by any public utility, together with any other facts or information which the Commission may acquire or receive from an investigation of the books, records or papers or from an inspection of the property of such public utility, that the net income of such public utility after reasonable deductions for depreciation and other proper and necessary reserves, is in excess of the amount required for a reasonable return upon the value of said public utility's property used and useful in rendering its service to the public, provided however that in computing net income, deductions shall not be made for advertising expenses as prohibited under Section 9-225 of this Act, and if the Commission is of the opinion and so finds in said cause that a hearing to determine all of the issues involved in a final determination of rates or services will require more than 105 days of elapsed time, the Commission shall have the power in cases of such emergency and it is hereby given authority to at once enter a temporary order, after notice to said public utility, fixing a temporary schedule of rates, which order shall be forthwith binding upon said public utility; provided, however, that the Commission's power to order reductions in rates and charges of any public utility by means of any such temporary order, is limited to reductions which will absorb not more than the amount found by the Commission to be in excess of the amount of income as determined by the Commission necessary to provide a reasonable return on the value of the property of said public utility as found by the Commission as aforesaid; and provided, further, however, that no such temporary order shall remain in force or effect for a longer period than 9 months from its effective date, and a further period not to exceed 3 months in addition if so ordered by the Commission; and provided, further, that if upon the final disposition of the issues involved in such proceeding, the rates or charges as finally determined by said Commission or the court having jurisdiction of the subject matter are in excess of the rates and charges prescribed in said temporary order, then and in such event such public utility shall be permitted over such reasonable time as the Commission shall fix, to amortize and recover by means of a temporary increase over and above the rates and charges finally determined, such sum as shall represent the difference between the gross income obtained from the rates and charges prescribed in said temporary reduction order and the gross income which would have obtained, during the period such temporary reduction order was in effect, based upon the same volume, from the rates and charges finally determined.

(b) If the Commission enters upon a hearing concerning the propriety of any proposed rate or other charge, classification, contract, practice, rule or regulation pursuant to Section 9-201, and if the Commission is of the opinion and so finds in said cause that a hearing to determine all of the issues involved in a final determination of rates or services will require more than 120 days of elapsed time, the Commission shall have the power to enter a temporary order fixing a temporary schedule of rates after hearing, which order shall be forthwith binding upon the public utility. As soon as practicable after the effective date of this amendatory Act of 1985, the Commission shall determine by rule the facts and circumstances which must be established by the utility in order to justify the grant of a temporary rate increase as provided herein. The Commission shall determine any temporary rate increase according to previously established standards until the time such rules become effective.

In any case in which the Commission grants interim relief, the Commission shall, upon final disposition of the proposed permanent change in rates or other charges, classification, contract, practice, rule or regulation, also review the propriety of its prior award of interim relief based upon the criteria used by the Commission in granting the interim rate relief. If, upon such review, the Commission determines that such interim rates or charges were in excess of the rates or charges which should have been prescribed in its temporary order, the Commission shall require the public utility to refund such sum as shall represent the difference between the gross income obtained from the rates or charges prescribed in said temporary increase order and the gross income which would have been obtained during the period such temporary increase order was in effect based upon the same volume, from the rates and charges which the Commission upon final review determines were appropriate. Any refund shall include interest calculated at a rate determined by the Commission and shall be returned according to procedures prescribed by the Commission.

(Source: P.A. 84-617; 84-1118.)

(220 ILCS 5/9-210) (from Ch. 111 2/3, par. 9-210)

Sec. 9-210. The Commission shall have power to ascertain the value of the property of every public utility in this State and every fact which in its judgment may or does have any bearing on such value. In all proceedings before the Commission, initiated by the Commission upon its own motion, or initiated by an application of such public utility, in which the value of the property of any public utility or utilities is an issue, the burden of establishing such value shall be upon such public utility or utilities. In making such valuation the Commission may avail itself of any information, books, documents, or records in the possession of any officer, department or board of the State or any subdivision thereof. The Commission shall have power to make revaluation from time to time and also to ascertain the value of all new construction, extensions, and additions to the property of every public utility.

For purposes of establishing the value of public utility property, when determining rates or charges, or for any other reason, the Commission may base its determination on the original cost of such property.

(Source: P.A. 84-617.)

(220 ILCS 5/9-210.5)

(Section scheduled to be repealed on June 1, 2028)

Sec. 9-210.5. Valuation of water and sewer utilities.

(a) In this Section:

"Disinterested" means that the person directly involved (1) is not a director, officer, or an employee of the large public utility or the water or sewer utility or its direct affiliates or subsidiaries for at least 12 months before becoming engaged under this Section; (2) shall not derive a material financial benefit from the sale of the water or sewer utility other than fees for services rendered, and (3) shall not have a member of the person's immediate family, including a spouse, parents or spouse's parents, children or spouses of children, or siblings and their spouses or children, be a director, officer, or employee of either the large public utility or water or sewer utility or the water or sewer utility or its direct affiliates or subsidiaries for at least 12 months before becoming engaged under this Section or receive a material financial benefit from the sale of the water or sewer utility other than fees for services rendered.

"District" means a service area of a large public utility whose customers are subject to the same rate tariff.

"Large public utility" means an investor-owned public utility that:

(1) is subject to regulation by the Illinois Commerce Commission under this Act;

(2) regularly provides water or sewer service to more than 15,000 customer connections;

(3) provides safe and adequate service; and

(4) is not a water or sewer utility as defined in this subsection (a).

"Next rate case" means a large public utility's first general rate case after the date the large public utility acquires the water or sewer utility where the acquired water or sewer utility's cost of service is considered as part of determining the large public utility's resulting rates.

"Prior rate case" means a large public utility's general rate case resulting in the rates in effect for the large public utility at the time it acquires the water or sewer utility.

"Utility service source" means the water or sewer utility or large public utility from which the customer receives its utility service type.

"Utility service type" means water utility service or sewer utility service or water and sewer utility service.

"Water or sewer utility" means any of the following:

(1) a public utility that regularly provides water or sewer service to 6,000 or fewer customer connections;

(2) a water district, including, but not limited to, a public water district, water service district, or surface water protection district, or a sewer district of any kind established as a special district under the laws of this State that regularly provides water or sewer service;

(3) a waterworks system or sewerage system established under the Township Code that regularly provides water or sewer service; or

(4) a water system or sewer system owned by a municipality that regularly provides water or sewer service; and

(5) any other entity that is not a public utility that regularly provides water or sewer service.

(b) Notwithstanding any other provision of this Act, a large public utility that acquires a water or sewer utility may request that the Commission use, and, if so requested, the Commission shall use, the procedures set forth under this Section to establish the ratemaking rate base of that water or sewer utility at the time when it is acquired by the large public utility.

(c) If a large public utility elects the procedures under this Section to establish the rate base of a water or sewer utility that it is acquiring, then 3 appraisals shall be performed. The average of these 3 appraisals shall represent the fair market value of the water or sewer utility that is being acquired. The appraisals shall be performed by 3 appraisers approved by the Commission's Executive Director or designee and engaged by either the water or sewer utility being acquired or by the large public utility. Each appraiser shall be engaged on reasonable terms approved by the Commission. Each appraiser shall be a disinterested person licensed as a State certified general real estate appraiser under the Real Estate Appraiser Licensing Act of 2002.

Each appraiser shall:

(1) be sworn to determine the fair market value of the water or sewer utility by establishing the amount for which the water or sewer utility would be sold in a voluntary transaction between a willing buyer and willing seller under no obligation to buy or sell;

(2) determine fair market value in compliance with the Uniform Standards of Professional Appraisal Practice;

(3) engage one disinterested engineer who is licensed in this State, and who may be the same engineer that is engaged by the other appraisers, to prepare an assessment of the tangible assets of the water or sewer utility, which is to be incorporated into the appraisal under the cost approach;

(4) request from the manager of the Accounting Department, if the water or sewer utility is a public utility that is regulated by the Commission, a list of investments made by the water or sewer utility that had been disallowed previously and that shall be excluded from the calculation of the large public utility's rate base in its next rate case; and

(5) return their appraisal, in writing, to the water or sewer utility and large public utility in a reasonable and timely manner.

If the appraiser cannot engage an engineer, as described in paragraph (3) of this subsection (c), within 30 days after the appraiser is engaged, then the Commission's Executive Director or designee shall recommend the engineer the appraiser should engage. The Commission's Executive Director or designee shall provide his or her recommendation within 30 days after he or she is officially notified of the appraiser's failure to engage an engineer and the appraiser shall promptly work to engage the recommended engineer. If the appraiser is unable to negotiate reasonable engagement terms with the recommended engineer within 15 days after the recommendation by the Commission's Executive Director or designee, then the appraiser shall notify the Commission's Executive Director or designee and the process shall be repeated until an engineer is successfully engaged.

(d) The lesser of (i) the purchase price or (ii) the fair market value determined under subsection (c) of this Section shall constitute the rate base associated with the water or sewer utility as acquired by and incorporated into the rate base of the district designated by the acquiring large public utility under this Section, subject to any adjustments that the Commission deems necessary to ensure such rate base reflects prudent and useful investments in the provision of public utility service. The reasonable transaction and closing costs incurred by the large public utility shall be treated consistent with the applicable accounting standards under this Act. The total amount of all of the appraisers' fees to be included in the transaction and closing costs shall not exceed the greater of $15,000 or 5% of the appraised value of the water or sewer utility being acquired. This rate base treatment shall not be deemed to violate this Act, including, but not limited to, any Sections in Articles VIII and IX of this Act that might be affected by this Section. Any acquisition of a water or sewer utility that affects the cumulative base rates of the large public utility's existing ratepayers in the tariff group into which the water or sewer utility is to be combined by less than (1) 2.5% at the time of the acquisition for any single acquisition completed under this Section or (2) 5% for all acquisitions completed under this Section before the Commission's final order in the next rate case shall not be deemed to violate Section 7-204 or any other provision of this Act.

In the Commission's order that approves the large public utility's acquisition of the water or sewer utility, the Commission shall issue its decision establishing (1) the ratemaking rate base of the water or sewer utility; (2) the district or tariff group with which the water or sewer utility shall be combined for ratemaking purposes, if such combination has been proposed by the large public utility; and (3) the rates to be charged to customers in the water or sewer utility.

(e) If the water or sewer utility being acquired is owned by the State or any political subdivision thereof, then the water or sewer utility must inform the public of the terms of its acquisition by the large public utility by (1) holding a public meeting prior to the acquisition and (2) causing to be published, in a newspaper of general circulation in the area that the water or sewer utility operates, a notice setting forth the terms of its acquisition by the large public utility and options that shall be available to assist customers to pay their bills after the acquisition.

(f) The large public utility may recommend the district or tariff group of which the water or sewer utility shall, for ratemaking purposes, become a part after the acquisition, or may recommend a lesser rate for the water or sewer utility. If the large public utility recommends a lesser rate, it shall submit to the Commission its proposed rate schedule and the proposed final tariff group for the acquired water or sewer utility. The Commission's approved district or tariff group or rates shall be consistent with the large public utility's recommendation, unless such recommendation can be shown to be contrary to the public interest.

(g) From the date of acquisition until the date that new rates are effective in the acquiring large public utility's next rate case, the customers of the acquired water or sewer utility shall pay the approved then-existing rates of the district or tariff group as ordered by the Commission, or some lesser rates as recommended by the large public utility and approved by the Commission under subsection (f); provided, that, if the application of such rates of the large public utility to customers of the acquired water or sewer utility using 54,000 gallons annually results in an increase to the total annual bill of customers of the acquired water or sewer utility, exclusive of fire service or related charges, then the large public utility's rates charged to the customers of the acquired water or sewer utility shall be uniformly reduced, if any reduction is required, by the percent that results in the total annual bill, exclusive of fire services or related charges, for the customers of the acquired water or sewer utility using 54,000 gallons being equal to 1.5% of the latest median household income as reported by the United States Census Bureau for the most applicable community or county. For each customer of the water or sewer utility with potable water usage values that cannot be reasonably obtained, a value of 4,500 gallons per month shall be assigned. These rates shall not be deemed to violate this Act including, but not limited to, Section 9-101 and any other applicable Sections in Articles VIII and IX of this Act. The Commission shall issue its decision establishing the rates effective for the water or sewer utility immediately following an acquisition in its order approving the acquisition.

(h) In the acquiring large public utility's next rate case, the water or sewer utility and the district or tariff group ordered by the Commission and their costs of service may be combined under the same rate tariff. This rate tariff shall be based on allocation of costs of service of the acquired water or sewer utility and the large public utility's district or tariff group ordered by the Commission and utilizing a rate design that does not distinguish among customers on the basis of utility service source or type. This rate tariff shall not be deemed to violate this Act including, but not limited to, Section 9-101 of this Act. In the acquiring large public utility's 2 rate cases after an acquisition, but in no subsequent rate case, the large public utility may file a rate tariff for a water or sewer utility acquired under this Section that establishes lesser rates than the district or tariff group into which the water or sewer utility is to be combined. Those lesser rates shall not be deemed to violate Section 7-204 or any other provision of this Act if they affect the cumulative base rates of the large public utility's existing rate payers in the district or tariff by less than 2.5%.

(i) Any post-acquisition improvements made by the large public utility in the water or sewer utility shall accrue a cost for financing set at the large public utility's determined rate for allowance for funds used during construction, inclusive of the debt, equity, and income tax gross up components, after the date on which the expenditure was incurred by the large public utility until the investment has been in service for a 4-year period or, if sooner, until the time the rates are implemented in the large public utility's next rate case.

Any post-acquisition improvements made by the large public utility in the water or sewer utility shall not be depreciated for ratemaking purposes from the date on which the expenditure was incurred by the large public utility until the investment has been in service for a 4-year period or, if sooner, until the time the rates are implemented in the large public utility's next rate case.

(j) This Section shall be exclusively applied to large public utilities in the voluntary and mutually agreeable acquisition of water or sewer utilities. Any petitions filed with the Commission related to the acquisitions described in this Section, including petitions seeking approvals or certificates required by this Act, shall be deemed approved unless the Commission issues its final order within 11 months after the date the large public utility filed its initial petition. This Section shall only apply to utilities providing water or sewer service and shall not be construed in any manner to apply to electric corporations, natural gas corporations, or any other utility subject to this Act.

(k) Nothing in this Section shall prohibit a party from declining to proceed with an acquisition or be deemed as establishing the final purchase price of an acquisition.

(l) In the Commission's order that approves the large utility's acquisition of the water or sewer utility, the Commission shall address each aspect of the acquisition transaction for which approval is required under the Act.

(m) Any contractor or subcontractor that performs work on a water or sewer utility acquired by a large public utility under this Section shall be a responsible bidder as described in Section 30-22 of the Illinois Procurement Code. The contractor or subcontractor shall submit evidence of meeting the requirements to be a responsible bidder as described in Section 30-22 to the water or sewer utility. Any new water or sewer facility built as a result of the acquisition shall require the contractor to enter into a project labor agreement. The large public utility acquiring the water or sewer utility shall offer employee positions to qualified employees of the acquired water or sewer utility.

(n) This Section is repealed on June 1, 2028.

(Source: P.A. 102-149, eff. 1-1-22.)

(220 ILCS 5/9-210.6)

Sec. 9-210.6. Continuation of Section 9-210.5 of this Act; validation.

(a) The General Assembly finds and declares that:

(1) Public Act 100-751, which took effect on August 10, 2018, contained provisions that would have changed the repeal date for Section 9-210.5 of this Act from June 1, 2018 to June 1, 2028.

(2) The Statute on Statutes sets forth general rules on the repeal of statutes and the construction of multiple amendments, but Section 1 of that Act also states that these rules will not be observed when the result would be "inconsistent with the manifest intent of the General Assembly or repugnant to the context of the statute".

(3) This amendatory Act of the 100th General Assembly manifests the intention of the General Assembly to extend the repeal date for Section 9-210.5 of this Act and have Section 9-210.5 of this Act, as amended by Public Act 100-751, continue in effect until June 1, 2028.

(b) Any construction of this Act that results in the repeal of Section 9-210.5 of this Act on June 1, 2018 would be inconsistent with the manifest intent of the General Assembly and repugnant to the context of this Act.

(c) It is hereby declared to have been the intent of the General Assembly that Section 9-210.5 of this Act shall not be subject to repeal on June 1, 2018.

(d) Section 9-210.5 of this Act shall be deemed to have been in continuous effect since August 9, 2013 (the effective date of Public Act 98-213), and it shall continue to be in effect, as amended by Public Act 100-751, until it is otherwise lawfully amended or repealed. All previously enacted amendments to the Section taking effect on or after August 9, 2013, are hereby validated.

(e) In order to ensure the continuing effectiveness of Section 9-210.5 of this Act, that Section is set forth in full and reenacted by this amendatory Act of the 100th General Assembly. In this amendatory Act of the 100th General Assembly, the base text of the reenacted Section is set forth as amended by Public Act 100-751.

(f) All actions of the Commission or any other person or entity taken in reliance on or pursuant to Section 9-210.5 are hereby validated.

(g) Section 9-210.5 of this Act applies to all proceedings pending on or filed on or before the effective date of this amendatory Act of the 100th General Assembly.

(Source: P.A. 100-1151, eff. 6-1-19.)

(220 ILCS 5/9-211) (from Ch. 111 2/3, par. 9-211)

Sec. 9-211. The Commission, in any determination of rates or charges, shall include in a utility's rate base only the value of such investment which is both prudently incurred and used and useful in providing service to public utility customers.

(Source: P.A. 84-617.)

(220 ILCS 5/9-211.7)

Sec. 9-211.7. Financial assistance; water and sewer utilities.

(a) On and after the effective date of this amendatory Act of the 102nd General Assembly, notwithstanding any other provision of this Act, a water or sewer utility subject to the jurisdiction of the Commission, after receiving approval from the Commission, shall be allowed to offer a financial assistance program designed for bill payment assistance for low-income customers in accordance with the Water and Sewer Financial Assistance Act. A water or sewer utility subject to the jurisdiction of the Commission shall petition the Commission for such approval, and the Commission shall render its decision within 90 days after receiving such petition. If no decision is rendered by the Commission within 90 days, then the petition shall be deemed to be approved.

(b) The costs of a financial assistance program offered by a water or sewer utility subject to the jurisdiction of the Commission, excluding such costs deemed by the Commission to be not reimbursable, shall be reimbursed from the Water and Sewer Low-Income Assistance Fund established pursuant to the Water and Sewer Financial Assistance Act. The utility shall submit a bill to the Department of Commerce and Economic Opportunity, which shall be promptly paid out of such funds or may net such costs against moneys it would otherwise remit to the Fund. The water or sewer utility shall provide a report to the Commission on a quarterly basis accounting for moneys reimbursed or netted through the Fund.

(c) A water or sewer utility subject to the jurisdiction of the Commission providing a financial assistance program pursuant to the Water and Sewer Financial Assistance Act in this State shall be permitted to recover costs of those assessments through a tariff filed with and approved by the Commission. The tariff shall be established outside the context of a general rate case and shall be applicable to the utility's customers.

(Source: P.A. 102-262, eff. 8-6-21.)

(220 ILCS 5/9-212) (from Ch. 111 2/3, par. 9-212)

Sec. 9-212. No new electric utility generating plant or gas production facility, or significant addition to existing facilities or plant, shall be included in a utility's rate base unless and until the utility proves, and the Commission determines, that such plant or facility is both prudent and used and useful in providing utility service to the utility's customers. For purposes of this Section, "prudent" means that at the time of certification, initiation of construction and each subsequent evaluation of any construction project until the time of completion, based on the evidence introduced in any hearings and all information which was known or should have been known at the time, and relevant planning and certification criteria, it was prudent and reasonable to conclude that the generating or production facility would be used and useful in providing service to customers at the time of completion. If the Commission has issued a certificate of public convenience and necessity for the completed facility, and to the extent that the Commission approves continued construction upon reevaluation subsequent to certification, such actions shall constitute prima facie evidence of the prudence of construction. If the Commission determines as a result of reevaluation during construction that the facility should not be completed, such determination shall constitute prima facie evidence that subsequent construction expenditures were imprudent.

A generation or production facility is used and useful only if, and only to the extent that, it is necessary to meet customer demand or economically beneficial in meeting such demand. No generation or production facility shall be found used and useful until and unless it is capable of generation or production at significant operating levels on a consistent and sustainable basis. Any pollution control devices for the control of sulfur dioxide emissions installed or used in accordance with, and up to the cost specified in, an order or supplemental order of the Commission entered pursuant to subsection (e) of Section 8-402.1 shall be deemed prudent and shall, upon being placed into operation on a consistent, sustainable basis by the public utility, be deemed used and useful.

(Source: P.A. 90-655, eff. 7-30-98.)

(220 ILCS 5/9-213) (from Ch. 111 2/3, par. 9-213)

Sec. 9-213. The cost of new electric utility generating plants and significant additions to electric utility generating plants shall not be included in the rate base of any utility unless such cost is reasonable. Prior to including the cost of plants or additions to utility plants in the rate base, the Commission shall conduct an audit of such costs in order to ascertain whether the cost associated with the new generating plant or the addition to electric utility generating plant is reasonable. However, the Commission may, for good cause shown in individual cases, waive the auditing requirement for any generating facility which meets all of the following requirements:

(1) the facility is wholly owned and operated by a public utility, as otherwise defined in this Act, which serves less than 20,000 electric customers within the State of Illinois, and

(2) the facility is designed to generate less than 50 megawatts of electricity, and

(3) the facility is located outside of the State of Illinois.

If the Commission is unable to conduct such an audit, the Commission shall arrange for it to be conducted by persons independent of the utility and selected by the Commission. The cost of such an independent audit shall be borne initially by the utility, but shall be recovered as an expense through normal ratemaking procedures. Any such audits shall be conducted in accordance with generally accepted auditing standards and shall include but not be limited to costs associated with materials, labor, equipment, professional services and other direct and indirect costs.

"Significant additions to the electric utility generating plant", as used in this Section, shall not include a public utility's investment in pollution control devices for the control of sulfur dioxide emissions. Nothing in this Section is intended to affect the provisions of Section 9-214 of this Act.

"Reasonable", as used in this Section, means that a utility's decisions, construction, and supervision of construction, underlying the costs of new electric utility generating plants and significant additions to electric utility generating plants resulted in efficient, economical and timely construction. In determining the reasonableness of plant costs, the Commission shall consider the knowledge and circumstances prevailing at the time of each relevant utility decision or action.

Nothing in this Section shall prevent or limit the Commission from either entering into and conducting joint audits concerning such electric generating plants with the regulatory authority of another state, or from relying on audits conducted by the regulatory authority of another state in lieu of an audit as required by this Section.

(Source: P.A. 87-435.)

(220 ILCS 5/9-214) (from Ch. 111 2/3, par. 9-214)

Sec. 9-214. (a) As used in this Section:

(1) "CWIP" means those assets which are recorded as construction work in progress on a public utility's books of accounts maintained in accordance with the applicable regulations and orders of the Commission.

(2) "Rate base" means the original cost value of the property on which a return is allowed.

(3) "CWIP ratio" means the fraction, expressed as a percentage, calculated by dividing the amount of CWIP included in a public utility's rate base by the utility's rate base.

(4) "Existing CWIP" means the amount of CWIP included in the rate base on December 1, 1983.

(b) In any determination under Section 9-201, 9-202 or 9-250 of this Act in a proceeding begun on or after December 1, 1983:

(1) For any public utility with a CWIP ratio on December 1, 1983, which is less than 15%, the Commission shall not include in the rate base for such public utility an amount for CWIP to exceed 80% of existing CWIP for the period from December 1, 1983 through December 31, 1984, and 60% of existing CWIP for the period from January 1, 1985 through December 31, 1985 and 40% of existing CWIP for the period from January 1, 1986 through December 31, 1986, and 20% of existing CWIP for the period from January 1, 1987 through December 31, 1987.

(2) For any public utility with a CWIP ratio on December 1, 1983 which is greater than or equal to 15%, the Commission shall not include in the rate base for such public utility an amount for CWIP in excess of the amount of CWIP included in the rate base on December 1, 1983, plus 50% of the allowed construction expenses incurred by the public utility from the date of the most recent rate determination by the Commission prior to December 1, 1983.

(c) The limitations set forth in paragraph (b) of this Section shall not be interpreted as an expansion of the Commission's authority to include CWIP in the rate base, but rather solely as a limitation thereon.

(d) The Commission shall not include an amount for CWIP in the rate base for any public utility for the period after December 31, 1988.

(e) Notwithstanding the provisions of paragraphs (b) and (d) of this Section the Commission may include in the rate base of a public utility an amount for CWIP for a public utility's investment which is scheduled to be placed in service within 12 months of the date of the rate determination. For the purposes of this paragraph nuclear generating facilities shall be considered to be in service upon the commencement of electric generation.

(f) Notwithstanding the provisions of paragraph (b) and (d), the Commission may include in the rate base of a public utility an amount of CWIP for a public utility's investment in pollution control devices for the control of sulfur dioxide emissions and the purification of water and sewage; provided, however, that upon application by a public utility which is constructing one or more pollution control devices for the control of sulfur dioxide emissions as part of a Clean Air Act compliance plan approved by the Commission pursuant to subsection (e) of Section 8-402.1, the Commission shall include in such public utility's rate base an amount of CWIP equal to its investment in such pollution control device or devices, but not to exceed the estimated cost of such facilities specified in the Commission's order or supplemental order pursuant to subsection (e) of Section 8-402.1. For purposes of this subsection (f), the public utility's investment shall not include the amount of any state, federal or other grants provided to the public utility to fund the design, acquisition, construction, installation and testing of pollution control devices for the control of sulfur dioxide emissions.

(g) Except for those amounts of CWIP described in paragraphs (e) and (f) of this Section, the Commission shall consider, in any rate filing subsequent to the coming on line of any new utility plant where CWIP funds have been allowed in rate base, a rate moderation plan directed towards allowing an appropriate return to ratepayers for previous amounts attributable to CWIP funds.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/9-215) (from Ch. 111 2/3, par. 9-215)

Sec. 9-215. The Commission shall have power to consider, on a case by case basis, the status of a utility's capacity and to determine whether or not such utility's capacity is in excess of that reasonably necessary to provide adequate and reliable electric service. Excess capacity for purposes of this Section shall mean capacity in excess of that reasonably necessary to provide adequate and reliable electric service. Such consideration shall be related to the utility's historic and projected peak.

The Commission is empowered to make appropriate and equitable adjustments to rates for utility service upon a finding of excess capacity.

With respect to generating capacity existing or under construction on the effective date of this amendatory Act of 1985, any such determination and adjustment to rates, and any determination as to whether such capacity is used and useful for any purpose under this Act, shall be limited to the determination and adjustment, if any, appropriate under the law in effect prior to such effective date.

(Source: P.A. 84-617.)

(220 ILCS 5/9-215.1) (from Ch. 111 2/3, par. 9-215.1)

Sec. 9-215.1. Capacity purchased from a qualified local solid waste energy facility shall not be included in the calculation of an electric utility's electricity generating capacity for the purposes of this Act, and shall not affect the determination of property that is used and useful for purposes of this Act.

(Source: P.A. 85-882.)

(220 ILCS 5/9-216)

Sec. 9-216. (Repealed).

(Source: P.A. 90-655, eff. 7-30-98. Repealed by P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/9-217) (from Ch. 111 2/3, par. 9-217)

Sec. 9-217. In each case or proceeding to determine the reasonableness of rates for any electric utility which involves the proposed inclusion of a significant new generation or production facility in rate base, the Commission may consider the adoption of a rate moderation plan which is designed to diminish the immediate rate impact of such proposed inclusion.

(Source: P.A. 84-617.)

(220 ILCS 5/9-220) (from Ch. 111 2/3, par. 9-220)

Sec. 9-220. Rate changes based on changes in fuel costs.

(a) Notwithstanding the provisions of Section 9-201, the Commission may authorize the increase or decrease of rates and charges based upon changes in the cost of fuel used in the generation or production of electric power, changes in the cost of purchased power, or changes in the cost of purchased gas through the application of fuel adjustment clauses or purchased gas adjustment clauses. The Commission may also authorize the increase or decrease of rates and charges based upon expenditures or revenues resulting from the purchase or sale of emission allowances created under the federal Clean Air Act Amendments of 1990, through such fuel adjustment clauses, as a cost of fuel. For the purposes of this paragraph, cost of fuel used in the generation or production of electric power shall include the amount of any fees paid by the utility for the implementation and operation of a process for the desulfurization of the flue gas when burning high sulfur coal at any location within the State of Illinois irrespective of the attainment status designation of such location; but shall not include transportation costs of coal (i) except to the extent that for contracts entered into on and after the effective date of this amendatory Act of 1997, the cost of the coal, including transportation costs, constitutes the lowest cost for adequate and reliable fuel supply reasonably available to the public utility in comparison to the cost, including transportation costs, of other adequate and reliable sources of fuel supply reasonably available to the public utility, or (ii) except as otherwise provided in the next 3 sentences of this paragraph. Such costs of fuel shall, when requested by a utility or at the conclusion of the utility's next general electric rate proceeding, whichever shall first occur, include transportation costs of coal purchased under existing coal purchase contracts. For purposes of this paragraph "existing coal purchase contracts" means contracts for the purchase of coal in effect on the effective date of this amendatory Act of 1991, as such contracts may thereafter be amended, but only to the extent that any such amendment does not increase the aggregate quantity of coal to be purchased under such contract. Nothing herein shall authorize an electric utility to recover through its fuel adjustment clause any amounts of transportation costs of coal that were included in the revenue requirement used to set base rates in its most recent general rate proceeding. Cost shall be based upon uniformly applied accounting principles. Annually, the Commission shall initiate public hearings to determine whether the clauses reflect actual costs of fuel, gas, power, or coal transportation purchased to determine whether such purchases were prudent, and to reconcile any amounts collected with the actual costs of fuel, power, gas, or coal transportation prudently purchased. In each such proceeding, the burden of proof shall be upon the utility to establish the prudence of its cost of fuel, power, gas, or coal transportation purchases and costs. The Commission shall issue its final order in each such annual proceeding for an electric utility by December 31 of the year immediately following the year to which the proceeding pertains, provided, that the Commission shall issue its final order with respect to such annual proceeding for the years 1996 and earlier by December 31, 1998.

(b) A public utility providing electric service, other than a public utility described in subsections (e) or (f) of this Section, may at any time during the mandatory transition period file with the Commission proposed tariff sheets that eliminate the public utility's fuel adjustment clause and adjust the public utility's base rate tariffs by the amount necessary for the base fuel component of the base rates to recover the public utility's average fuel and power supply costs per kilowatt-hour for the 2 most recent years for which the Commission has issued final orders in annual proceedings pursuant to subsection (a), where the average fuel and power supply costs per kilowatt-hour shall be calculated as the sum of the public utility's prudent and allowable fuel and power supply costs as found by the Commission in the 2 proceedings divided by the public utility's actual jurisdictional kilowatt-hour sales for those 2 years. Notwithstanding any contrary or inconsistent provisions in Section 9-201 of this Act, in subsection (a) of this Section or in any rules or regulations promulgated by the Commission pursuant to subsection (g) of this Section, the Commission shall review and shall by order approve, or approve as modified, the proposed tariff sheets within 60 days after the date of the public utility's filing. The Commission may modify the public utility's proposed tariff sheets only to the extent the Commission finds necessary to achieve conformance to the requirements of this subsection (b). During the 5 years following the date of the Commission's order, but in any event no earlier than January 1, 2007, a public utility whose fuel adjustment clause has been eliminated pursuant to this subsection shall not file proposed tariff sheets seeking, or otherwise petition the Commission for, reinstatement of a fuel adjustment clause.

(c) Notwithstanding any contrary or inconsistent provisions in Section 9-201 of this Act, in subsection (a) of this Section or in any rules or regulations promulgated by the Commission pursuant to subsection (g) of this Section, a public utility providing electric service, other than a public utility described in subsection (e) or (f) of this Section, may at any time during the mandatory transition period file with the Commission proposed tariff sheets that establish the rate per kilowatt-hour to be applied pursuant to the public utility's fuel adjustment clause at the average value for such rate during the preceding 24 months, provided that such average rate results in a credit to customers' bills, without making any revisions to the public utility's base rate tariffs. The proposed tariff sheets shall establish the fuel adjustment rate for a specific time period of at least 3 years but not more than 5 years, provided that the terms and conditions for any reinstatement earlier than 5 years shall be set forth in the proposed tariff sheets and subject to modification or approval by the Commission. The Commission shall review and shall by order approve the proposed tariff sheets if it finds that the requirements of this subsection are met. The Commission shall not conduct the annual hearings specified in the last 3 sentences of subsection (a) of this Section for the utility for the period that the factor established pursuant to this subsection is in effect.

(d) A public utility providing electric service, or a public utility providing gas service may file with the Commission proposed tariff sheets that eliminate the public utility's fuel or purchased gas adjustment clause and adjust the public utility's base rate tariffs to provide for recovery of power supply costs or gas supply costs that would have been recovered through such clause; provided, that the provisions of this subsection (d) shall not be available to a public utility described in subsections (e) or (f) of this Section to eliminate its fuel adjustment clause. Notwithstanding any contrary or inconsistent provisions in Section 9-201 of this Act, in subsection (a) of this Section, or in any rules or regulations promulgated by the Commission pursuant to subsection (g) of this Section, the Commission shall review and shall by order approve, or approve as modified in the Commission's order, the proposed tariff sheets within 240 days after the date of the public utility's filing. The Commission's order shall approve rates and charges that the Commission, based on information in the public utility's filing or on the record if a hearing is held by the Commission, finds will recover the reasonable, prudent and necessary jurisdictional power supply costs or gas supply costs incurred or to be incurred by the public utility during a 12 month period found by the Commission to be appropriate for these purposes, provided, that such period shall be either (i) a 12 month historical period occurring during the 15 months ending on the date of the public utility's filing, or (ii) a 12 month future period ending no later than 15 months following the date of the public utility's filing. The public utility shall include with its tariff filing information showing both (1) its actual jurisdictional power supply costs or gas supply costs for a 12 month historical period conforming to (i) above and (2) its projected jurisdictional power supply costs or gas supply costs for a future 12 month period conforming to (ii) above. If the Commission's order requires modifications in the tariff sheets filed by the public utility, the public utility shall have 7 days following the date of the order to notify the Commission whether the public utility will implement the modified tariffs or elect to continue its fuel or purchased gas adjustment clause in force as though no order had been entered. The Commission's order shall provide for any reconciliation of power supply costs or gas supply costs, as the case may be, and associated revenues through the date that the public utility's fuel or purchased gas adjustment clause is eliminated. During the 5 years following the date of the Commission's order, a public utility whose fuel or purchased gas adjustment clause has been eliminated pursuant to this subsection shall not file proposed tariff sheets seeking, or otherwise petition the Commission for, reinstatement or adoption of a fuel or purchased gas adjustment clause. Nothing in this subsection (d) shall be construed as limiting the Commission's authority to eliminate a public utility's fuel adjustment clause or purchased gas adjustment clause in accordance with any other applicable provisions of this Act.

(e) Notwithstanding any contrary or inconsistent provisions in Section 9-201 of this Act, in subsection (a) of this Section, or in any rules promulgated by the Commission pursuant to subsection (g) of this Section, a public utility providing electric service to more than 1,000,000 customers in this State may, within the first 6 months after the effective date of this amendatory Act of 1997, file with the Commission proposed tariff sheets that eliminate, effective January 1, 1997, the public utility's fuel adjustment clause without adjusting its base rates, and such tariff sheets shall be effective upon filing. To the extent the application of the fuel adjustment clause had resulted in net charges to customers after January 1, 1997, the utility shall also file a tariff sheet that provides for a refund stated on a per kilowatt-hour basis of such charges over a period not to exceed 6 months; provided however, that such refund shall not include the proportional amounts of taxes paid under the Use Tax Act, Service Use Tax Act, Service Occupation Tax Act, and Retailers' Occupation Tax Act on fuel used in generation. The Commission shall issue an order within 45 days after the date of the public utility's filing approving or approving as modified such tariff sheet. If the fuel adjustment clause is eliminated pursuant to this subsection, the Commission shall not conduct the annual hearings specified in the last 3 sentences of subsection (a) of this Section for the utility for any period after December 31, 1996 and prior to any reinstatement of such clause. A public utility whose fuel adjustment clause has been eliminated pursuant to this subsection shall not file a proposed tariff sheet seeking, or otherwise petition the Commission for, reinstatement of the fuel adjustment clause prior to January 1, 2007.

(f) Notwithstanding any contrary or inconsistent provisions in Section 9-201 of this Act, in subsection (a) of this Section, or in any rules or regulations promulgated by the Commission pursuant to subsection (g) of this Section, a public utility providing electric service to more than 500,000 customers but fewer than 1,000,000 customers in this State may, within the first 6 months after the effective date of this amendatory Act of 1997, file with the Commission proposed tariff sheets that eliminate, effective January 1, 1997, the public utility's fuel adjustment clause and adjust its base rates by the amount necessary for the base fuel component of the base rates to recover 91% of the public utility's average fuel and power supply costs for the 2 most recent years for which the Commission, as of January 1, 1997, has issued final orders in annual proceedings pursuant to subsection (a), where the average fuel and power supply costs per kilowatt-hour shall be calculated as the sum of the public utility's prudent and allowable fuel and power supply costs as found by the Commission in the 2 proceedings divided by the public utility's actual jurisdictional kilowatt-hour sales for those 2 years, provided, that such tariff sheets shall be effective upon filing. To the extent the application of the fuel adjustment clause had resulted in net charges to customers after January 1, 1997, the utility shall also file a tariff sheet that provides for a refund stated on a per kilowatt-hour basis of such charges over a period not to exceed 6 months. Provided however, that such refund shall not include the proportional amounts of taxes paid under the Use Tax Act, Service Use Tax Act, Service Occupation Tax Act, and Retailers' Occupation Tax Act on fuel used in generation. The Commission shall issue an order within 45 days after the date of the public utility's filing approving or approving as modified such tariff sheet. If the fuel adjustment clause is eliminated pursuant to this subsection, the Commission shall not conduct the annual hearings specified in the last 3 sentences of subsection (a) of this Section for the utility for any period after December 31, 1996 and prior to any reinstatement of such clause. A public utility whose fuel adjustment clause has been eliminated pursuant to this subsection shall not file a proposed tariff sheet seeking, or otherwise petition the Commission for, reinstatement of the fuel adjustment clause prior to January 1, 2007.

(g) The Commission shall have authority to promulgate rules and regulations to carry out the provisions of this Section.

(h) Any Illinois gas utility may enter into a contract on or before September 30, 2011 for up to 10 years of supply with any company for the purchase of substitute natural gas (SNG) produced from coal through the gasification process if the company has commenced construction of a clean coal SNG facility by July 1, 2012 and commencement of construction shall mean that material physical site work has occurred, such as site clearing and excavation, water runoff prevention, water retention reservoir preparation, or foundation development. The contract shall contain the following provisions: (i) at least 90% of feedstock to be used in the gasification process shall be coal with a high volatile bituminous rank and greater than 1.7 pounds of sulfur per million Btu content; (ii) at the time the contract term commences, the price per million Btu may not exceed $7.95 in 2008 dollars, adjusted annually based on the change in the Annual Consumer Price Index for All Urban Consumers for the Midwest Region as published in April by the United States Department of Labor, Bureau of Labor Statistics (or a suitable Consumer Price Index calculation if this Consumer Price Index is not available) for the previous calendar year; provided that the price per million Btu shall not exceed $9.95 at any time during the contract; (iii) the utility's supply contract for the purchase of SNG does not exceed 15% of the annual system supply requirements of the utility as of 2008; and (iv) the contract costs pursuant to subsection (h-10) of this Section shall not include any lobbying expenses, charitable contributions, advertising, organizational memberships, carbon dioxide pipeline or sequestration expenses, or marketing expenses.

Any gas utility that is providing service to more than 150,000 customers on August 2, 2011 (the effective date of Public Act 97-239) shall either elect to enter into a contract on or before September 30, 2011 for 10 years of SNG supply with the owner of a clean coal SNG facility or to file biennial rate proceedings before the Commission in the years 2012, 2014, and 2016, with such filings made after August 2, 2011 and no later than September 30 of the years 2012, 2014, and 2016 consistent with all requirements of 83 Ill. Adm. Code 255 and 285 as though the gas utility were filing for an increase in its rates, without regard to whether such filing would produce an increase, a decrease, or no change in the gas utility's rates, and the Commission shall review the gas utility's filing and shall issue its order in accordance with the provisions of Section 9-201 of this Act.

Within 7 days after August 2, 2011, the owner of the clean coal SNG facility shall submit to the Illinois Power Agency and each gas utility that is providing service to more than 150,000 customers on August 2, 2011 a copy of a draft contract. Within 30 days after the receipt of the draft contract, each such gas utility shall provide the Illinois Power Agency and the owner of the clean coal SNG facility with its comments and recommended revisions to the draft contract. Within 7 days after the receipt of the gas utility's comments and recommended revisions, the owner of the facility shall submit its responsive comments and a further revised draft of the contract to the Illinois Power Agency. The Illinois Power Agency shall review the draft contract and comments.

During its review of the draft contract, the Illinois Power Agency shall:

(1) review and confirm in writing that the terms stated in this subsection (h) are incorporated in the SNG contract;

(2) review the SNG pricing formula included in the contract and approve that formula if the Illinois Power Agency determines that the formula, at the time the contract term commences: (A) starts with a price of $6.50 per MMBtu adjusted by the adjusted final capitalized plant cost; (B) takes into account budgeted miscellaneous net revenue after cost allowance, including sale of SNG produced by the clean coal SNG facility above the nameplate capacity of the facility and other by-products produced by the facility, as approved by the Illinois Power Agency; (C) does not include carbon dioxide transportation or sequestration expenses; and (D) includes all provisions required under this subsection (h); if the Illinois Power Agency does not approve of the SNG pricing formula, then the Illinois Power Agency shall modify the formula to ensure that it meets the requirements of this subsection (h);

(3) review and approve the amount of budgeted miscellaneous net revenue after cost allowance, including sale of SNG produced by the clean coal SNG facility above the nameplate capacity of the facility and other by-products produced by the facility, to be included in the pricing formula; the Illinois Power Agency shall approve the amount of budgeted miscellaneous net revenue to be included in the pricing formula if it determines the budgeted amount to be reasonable and accurate;

(4) review and confirm in writing that using the EIA Annual Energy Outlook-2011 Henry Hub Spot Price, the contract terms set out in subsection (h), the reconciliation account terms as set out in subsection (h-15), and an estimated inflation rate of 2.5% for each corresponding year, that there will be no cumulative estimated increase for residential customers; and

(5) allocate the nameplate capacity of the clean coal SNG by total therms sold to ultimate customers by each gas utility in 2008; provided, however, no utility shall be required to purchase more than 42% of the projected annual output of the facility; additionally, the Illinois Power Agency shall further adjust the allocation only as required to take into account (A) adverse consolidation, derivative, or lease impacts to the balance sheet or income statement of any gas utility or (B) the physical capacity of the gas utility to accept SNG.

If the parties to the contract do not agree on the terms therein, then the Illinois Power Agency shall retain an independent mediator to mediate the dispute between the parties. If the parties are in agreement on the terms of the contract, then the Illinois Power Agency shall approve the contract. If after mediation the parties have failed to come to agreement, then the Illinois Power Agency shall revise the draft contract as necessary to confirm that the contract contains only terms that are reasonable and equitable. The Illinois Power Agency may, in its discretion, retain an independent, qualified, and experienced expert to assist in its obligations under this subsection (h). The Illinois Power Agency shall adopt and make public policies detailing the processes for retaining a mediator and an expert under this subsection (h). Any mediator or expert retained under this subsection (h) shall be retained no later than 60 days after August 2, 2011.

The Illinois Power Agency shall complete all of its responsibilities under this subsection (h) within 60 days after August 2, 2011. The clean coal SNG facility shall pay a reasonable fee as required by the Illinois Power Agency for its services under this subsection (h) and shall pay the mediator's and expert's reasonable fees, if any. A gas utility and its customers shall have no obligation to reimburse the clean coal SNG facility or the Illinois Power Agency of any such costs.

Within 30 days after commercial production of SNG has begun, the Commission shall initiate a review to determine whether the final capitalized plant cost of the clean coal SNG facility reflects actual incurred costs and whether the incurred costs were reasonable. In determining the actual incurred costs included in the final capitalized plant cost and the reasonableness of those costs, the Commission may in its discretion retain independent, qualified, and experienced experts to assist in its determination. The expert shall not own or control any direct or indirect interest in the clean coal SNG facility and shall have no contractual relationship with the clean coal SNG facility. If an expert is retained by the Commission, then the clean coal SNG facility shall pay the expert's reasonable fees. The fees shall not be passed on to a utility or its customers. The Commission shall adopt and make public a policy detailing the process for retaining experts under this subsection (h).

Within 30 days after completion of its review, the Commission shall initiate a formal proceeding on the final capitalized plant cost of the clean coal SNG facility at which comments and testimony may be submitted by any interested parties and the public. If the Commission finds that the final capitalized plant cost includes costs that were not actually incurred or costs that were unreasonably incurred, then the Commission shall disallow the amount of non-incurred or unreasonable costs from the SNG price under contracts entered into under this subsection (h). If the Commission disallows any costs, then the Commission shall adjust the SNG price using the price formula in the contract approved by the Illinois Power Agency under this subsection (h) to reflect the disallowed costs and shall enter an order specifying the revised price. In addition, the Commission's order shall direct the clean coal SNG facility to issue refunds of such sums as shall represent the difference between actual gross revenues and the gross revenue that would have been obtained based upon the same volume, from the price revised by the Commission. Any refund shall include interest calculated at a rate determined by the Commission and shall be returned according to procedures prescribed by the Commission.

Nothing in this subsection (h) shall preclude any party affected by a decision of the Commission under this subsection (h) from seeking judicial review of the Commission's decision.

(h-1) Any Illinois gas utility may enter into a sourcing agreement for up to 30 years of supply with the clean coal SNG brownfield facility if the clean coal SNG brownfield facility has commenced construction. Any gas utility that is providing service to more than 150,000 customers on July 13, 2011 (the effective date of Public Act 97-096) shall either elect to file biennial rate proceedings before the Commission in the years 2012, 2014, and 2016 or enter into a sourcing agreement or sourcing agreements with a clean coal SNG brownfield facility with an initial term of 30 years for either (i) a percentage of 43,500,000,000 cubic feet per year, such that the utilities entering into sourcing agreements with the clean coal SNG brownfield facility purchase 100%, allocated by total therms sold to ultimate customers by each gas utility in 2008 or (ii) such lesser amount as may be available from the clean coal SNG brownfield facility; provided that no utility shall be required to purchase more than 42% of the projected annual output of the clean coal SNG brownfield facility, with the remainder of such utility's obligation to be divided proportionately between the other utilities, and provided that the Illinois Power Agency shall further adjust the allocation only as required to take into account adverse consolidation, derivative, or lease impacts to the balance sheet or income statement of any gas utility.

A gas utility electing to file biennial rate proceedings before the Commission must file a notice of its election with the Commission within 60 days after July 13, 2011 or its right to make the election is irrevocably waived. A gas utility electing to file biennial rate proceedings shall make such filings no later than August 1 of the years 2012, 2014, and 2016, consistent with all requirements of 83 Ill. Adm. Code 255 and 285 as though the gas utility were filing for an increase in its rates, without regard to whether such filing would produce an increase, a decrease, or no change in the gas utility's rates, and notwithstanding any other provisions of this Act, the Commission shall fully review the gas utility's filing and shall issue its order in accordance with the provisions of Section 9-201 of this Act, regardless of whether the Commission has approved a formula rate for the gas utility.

Within 15 days after July 13, 2011, the owner of the clean coal SNG brownfield facility shall submit to the Illinois Power Agency and each gas utility that is providing service to more than 150,000 customers on July 13, 2011 a copy of a draft sourcing agreement. Within 45 days after receipt of the draft sourcing agreement, each such gas utility shall provide the Illinois Power Agency and the owner of a clean coal SNG brownfield facility with its comments and recommended revisions to the draft sourcing agreement. Within 15 days after the receipt of the gas utility's comments and recommended revisions, the owner of the clean coal SNG brownfield facility shall submit its responsive comments and a further revised draft of the sourcing agreement to the Illinois Power Agency. The Illinois Power Agency shall review the draft sourcing agreement and comments.

If the parties to the sourcing agreement do not agree on the terms therein, then the Illinois Power Agency shall retain an independent mediator to mediate the dispute between the parties. If the parties are in agreement on the terms of the sourcing agreement, the Illinois Power Agency shall approve the final draft sourcing agreement. If after mediation the parties have failed to come to agreement, then the Illinois Power Agency shall revise the draft sourcing agreement as necessary to confirm that the final draft sourcing agreement contains only terms that are reasonable and equitable. The Illinois Power Agency shall adopt and make public a policy detailing the process for retaining a mediator under this subsection (h-1). Any mediator retained to assist with mediating disputes between the parties regarding the sourcing agreement shall be retained no later than 60 days after July 13, 2011.

Upon approval of a final draft agreement, the Illinois Power Agency shall submit the final draft agreement to the Capital Development Board and the Commission no later than 90 days after July 13, 2011. The gas utility and the clean coal SNG brownfield facility shall pay a reasonable fee as required by the Illinois Power Agency for its services under this subsection (h-1) and shall pay the mediator's reasonable fees, if any. The Illinois Power Agency shall adopt and make public a policy detailing the process for retaining a mediator under this Section.

The sourcing agreement between a gas utility and the clean coal SNG brownfield facility shall contain the following provisions:

(1) Any and all coal used in the gasification process must be coal that has high volatile bituminous rank and greater than 1.7 pounds of sulfur per million Btu content.

(2) Coal and petroleum coke are feedstocks for the gasification process, with coal comprising at least 50% of the total feedstock over the term of the sourcing agreement unless the facility reasonably determines that it is necessary to use additional petroleum coke to deliver net consumer savings, in which case the facility shall use coal for at least 35% of the total feedstock over the term of any sourcing agreement and with the feedstocks to be procured in accordance with requirements of Section 1-78 of the Illinois Power Agency Act.

(3) The sourcing agreement has an initial term that once entered into terminates no more than 30 years after the commencement of the commercial production of SNG at the clean coal SNG brownfield facility.

(4) The clean coal SNG brownfield facility guarantees a minimum of $100,000,000 in consumer savings to customers of the utilities that have entered into sourcing agreements with the clean coal SNG brownfield facility, calculated in real 2010 dollars at the conclusion of the term of the sourcing agreement by comparing the delivered SNG price to the Chicago City-gate price on a weighted daily basis for each day over the entire term of the sourcing agreement, to be provided in accordance with subsection (h-2) of this Section.

(5) Prior to the clean coal SNG brownfield facility issuing a notice to proceed to construction, the clean coal SNG brownfield facility shall establish a consumer protection reserve account for the benefit of the customers of the utilities that have entered into sourcing agreements with the clean coal SNG brownfield facility pursuant to this subsection (h-1), with cash principal in the amount of $150,000,000. This cash principal shall only be recoverable through the consumer protection reserve account and not as a cost to be recovered in the delivered SNG price pursuant to subsection (h-3) of this Section. The consumer protection reserve account shall be maintained and administered by an independent trustee that is mutually agreed upon by the clean coal SNG brownfield facility, the utilities, and the Commission in an interest-bearing account in accordance with subsection (h-2) of this Section.

"Consumer protection reserve account principal maximum amount" shall mean the maximum amount of principal to be maintained in the consumer protection reserve account. During the first 2 years of operation of the facility, there shall be no consumer protection reserve account maximum amount. After the first 2 years of operation of the facility, the consumer protection reserve account maximum amount shall be $150,000,000. After 5 years of operation, and every 5 years thereafter, the trustee shall calculate the 5-year average balance of the consumer protection reserve account. If the trustee determines that during the prior 5 years the consumer protection reserve account has had an average account balance of less than $75,000,000, then the consumer protection reserve account principal maximum amount shall be increased by $5,000,000. If the trustee determines that during the prior 5 years the consumer protection reserve account has had an average account balance of more than $75,000,000, then the consumer protection reserve account principal maximum amount shall be decreased by $5,000,000.

(6) The clean coal SNG brownfield facility shall identify and sell economically viable by-products produced by the facility.

(7) Fifty percent of all additional net revenue, defined as miscellaneous net revenue from products produced by the facility and delivered during the month after cost allowance for costs associated with additional net revenue that are not otherwise recoverable pursuant to subsection (h-3) of this Section, including net revenue from sales of substitute natural gas derived from the facility above the nameplate capacity of the facility and other by-products produced by the facility, shall be credited to the consumer protection reserve account pursuant to subsection (h-2) of this Section.

(8) The delivered SNG price per million btu to be paid monthly by the utility to the clean coal SNG brownfield facility, which shall be based only upon the following: (A) a capital recovery charge, operations and maintenance costs, and sequestration costs, only to the extent approved by the Commission pursuant to paragraphs (1), (2), and (3) of subsection (h-3) of this Section; (B) the actual delivered and processed fuel costs pursuant to paragraph (4) of subsection (h-3) of this Section; (C) actual costs of SNG transportation pursuant to paragraph (6) of subsection (h-3) of this Section; (D) certain taxes and fees imposed by the federal government, the State, or any unit of local government as provided in paragraph (6) of subsection (h-3) of this Section; and (E) the credit, if any, from the consumer protection reserve account pursuant to subsection (h-2) of this Section. The delivered SNG price per million Btu shall proportionately reflect these elements over the term of the sourcing agreement.

(9) A formula to translate the recoverable costs and charges under subsection (h-3) of this Section into the delivered SNG price per million btu.

(10) Title to the SNG shall pass at a mutually agreeable point in Illinois, and may provide that, rather than the utility taking title to the SNG, a mutually agreed upon third-party gas marketer pursuant to a contract approved by the Illinois Power Agency or its designee may take title to the SNG pursuant to an agreement between the utility, the owner of the clean coal SNG brownfield facility, and the third-party gas marketer.

(11) A utility may exit the sourcing agreement without penalty if the clean coal SNG brownfield facility does not commence construction by July 1, 2015.

(12) A utility is responsible to pay only the Commission determined unit price cost of SNG that is purchased by the utility. Nothing in the sourcing agreement will obligate a utility to invest capital in a clean coal SNG brownfield facility.

(13) The quality of SNG must, at a minimum, be equivalent to the quality required for interstate pipeline gas before a utility is required to accept and pay for SNG gas.

(14) Nothing in the sourcing agreement will require a utility to construct any facilities to accept delivery of SNG. Provided, however, if a utility is required by law or otherwise elects to connect the clean coal SNG brownfield facility to an interstate pipeline, then the utility shall be entitled to recover pursuant to its tariffs all just and reasonable costs that are prudently incurred. Any costs incurred by the utility to receive, deliver, manage, or otherwise accommodate purchases under the SNG sourcing agreement will be fully recoverable through a utility's purchased gas adjustment clause rider mechanism in conjunction with a SNG brownfield facility rider mechanism. The SNG brownfield facility rider mechanism (A) shall be applicable to all customers who receive transportation service from the utility, (B) shall be designed to have an equal percent impact on the transportation services rates of each class of the utility's customers, and (C) shall accurately reflect the net consumer savings, if any, and above-market costs, if any, associated with the utility receiving, delivering, managing, or otherwise accommodating purchases under the SNG sourcing agreement.

(15) Remedies for the clean coal SNG brownfield facility's failure to deliver a designated amount for a designated period.

(16) The clean coal SNG brownfield facility shall make a good faith effort to ensure that an amount equal to not less than 15% of the value of its prime construction contract for the facility shall be established as a goal to be awarded to minority-owned businesses, women-owned businesses, and businesses owned by a person with a disability; provided that at least 75% of the amount of such total goal shall be for minority-owned businesses. "Minority-owned business", "women-owned business", and "business owned by a person with a disability" shall have the meanings ascribed to them in Section 2 of the Business Enterprise for Minorities, Women, and Persons with Disabilities Act.

(17) Prior to the clean coal SNG brownfield facility issuing a notice to proceed to construction, the clean coal SNG brownfield facility shall file with the Commission a certificate from an independent engineer that the clean coal SNG brownfield facility has (A) obtained all applicable State and federal environmental permits required for construction; (B) obtained approval from the Commission of a carbon capture and sequestration plan; and (C) obtained all necessary permits required for construction for the transportation and sequestration of carbon dioxide as set forth in the Commission-approved carbon capture and sequestration plan.

(h-2) Consumer protection reserve account. The clean coal SNG brownfield facility shall guarantee a minimum of $100,000,000 in consumer savings to customers of the utilities that have entered into sourcing agreements with the clean coal SNG brownfield facility, calculated in real 2010 dollars at the conclusion of the term of the sourcing agreement by comparing the delivered SNG price to the Chicago City-gate price on a weighted daily basis for each day over the entire term of the sourcing agreement. Prior to the clean coal SNG brownfield facility issuing a notice to proceed to construction, the clean coal SNG brownfield facility shall establish a consumer protection reserve account for the benefit of the retail customers of the utilities that have entered into sourcing agreements with the clean coal SNG brownfield facility pursuant to subsection (h-1), with cash principal in the amount of $150,000,000. Such cash principal shall only be recovered through the consumer protection reserve account and not as a cost to be recovered in the delivered SNG price pursuant to subsection (h-3) of this Section. The consumer protection reserve account shall be maintained and administered by an independent trustee that is mutually agreed upon by the clean coal SNG brownfield facility, the utilities, and the Commission in an interest-bearing account in accordance with the following:

(1) The clean coal SNG brownfield facility monthly shall calculate (A) the difference between the monthly delivered SNG price and the Chicago City-gate price, by comparing the delivered SNG price, which shall include the cost of transportation to the delivery point, if any, to the Chicago City-gate price on a weighted daily basis for each day of the prior month based upon a mutually agreed upon published index and (B) the overage amount, if any, by calculating the annualized incremental additional cost, if any, of the delivered SNG in excess of 2.015% of the average annual inflation-adjusted amounts paid by all gas distribution customers in connection with natural gas service during the 5 years ending May 31, 2010.

(2) During the first 2 years of operation of the facility:

(A) to the extent there is an overage amount, the consumer protection reserve account shall be used to provide a credit to reduce the SNG price by an amount equal to the overage amount; and

(B) to the extent the monthly delivered SNG price is less than or equal to the Chicago City-gate price, the utility shall credit the difference between the monthly delivered SNG price and the monthly Chicago City-gate price, if any, to the consumer protection reserve account. Such credit issued pursuant to this paragraph (B) shall be deemed prudent and reasonable and not subject to a Commission prudence review;

(3) After 2 years of operation of the facility, and monthly, on an on-going basis, thereafter:

(A) to the extent that the monthly delivered SNG price is less than or equal to the Chicago City-gate price, calculated using the weighted average of the daily Chicago City-gate price on a daily basis over the entire month, the utility shall credit the difference, if any, to the consumer protection reserve account. Such credit issued pursuant to this subparagraph (A) shall be deemed prudent and reasonable and not subject to a Commission prudence review;

(B) any amounts in the consumer protection reserve account in excess of the consumer protection reserve account principal maximum amount shall be distributed as follows: (i) if retail customers have not realized net consumer savings, calculated by comparing the delivered SNG price to the weighted average of the daily Chicago City-gate price on a daily basis over the entire term of the sourcing agreement to date, then 50% of any amounts in the consumer protection reserve account in excess of the consumer protection reserve account principal maximum shall be distributed to the clean coal SNG brownfield facility, with the remaining 50% of any such additional amounts being credited to retail customers, and (ii) if retail customers have realized net consumer savings, then 100% of any amounts in the consumer protection reserve account in excess of the consumer protection reserve account principal maximum shall be distributed to the clean coal SNG brownfield facility; provided, however, that under no circumstances shall the total cumulative amount distributed to the clean coal SNG brownfield facility under this subparagraph (B) exceed $150,000,000;

(C) to the extent there is an overage amount, after distributing the amounts pursuant to subparagraph (B) of this paragraph (3), if any, the consumer protection reserve account shall be used to provide a credit to reduce the SNG price by an amount equal to the overage amount;

(D) if retail customers have realized net consumer savings, calculated by comparing the delivered SNG price to the weighted average of the daily Chicago City-gate price on a daily basis over the entire term of the sourcing agreement to date, then after distributing the amounts pursuant to subparagraphs (B) and (C) of this paragraph (3), 50% of any additional amounts in the consumer protection reserve account in excess of the consumer protection reserve account principal maximum shall be distributed to the clean coal SNG brownfield facility, with the remaining 50% of any such additional amounts being credited to retail customers; provided, however, that if retail customers have not realized such net consumer savings, no such distribution shall be made to the clean coal SNG brownfield facility, and 100% of such additional amounts shall be credited to the retail customers to the extent the consumer protection reserve account exceeds the consumer protection reserve account principal maximum amount.

(4) Fifty percent of all additional net revenue, defined as miscellaneous net revenue after cost allowance for costs associated with additional net revenue that are not otherwise recoverable pursuant to subsection (h-3) of this Section, including net revenue from sales of substitute natural gas derived from the facility above the nameplate capacity of the facility and other by-products produced by the facility, shall be credited to the consumer protection reserve account.

(5) At the conclusion of the term of the sourcing agreement, to the extent retail customers have not saved the minimum of $100,000,000 in consumer savings as guaranteed in this subsection (h-2), amounts in the consumer protection reserve account shall be credited to retail customers to the extent the retail customers have saved the minimum of $100,000,000; 50% of any additional amounts in the consumer protection reserve account shall be distributed to the company, and the remaining 50% shall be distributed to retail customers.

(6) If, at the conclusion of the term of the sourcing agreement, the customers have not saved the minimum $100,000,000 in savings as guaranteed in this subsection (h-2) and the consumer protection reserve account has been depleted, then the clean coal SNG brownfield facility shall be liable for any remaining amount owed to the retail customers to the extent that the customers are provided with the $100,000,000 in savings as guaranteed in this subsection (h-2). The retail customers shall have first priority in recovering that debt above any creditors, except the original senior secured lender to the extent that the original senior secured lender has any senior secured debt outstanding, including any clean coal SNG brownfield facility parent companies or affiliates.

(7) The clean coal SNG brownfield facility, the utilities, and the trustee shall work together to take commercially reasonable steps to minimize the tax impact of these transactions, while preserving the consumer benefits.

(8) The clean coal SNG brownfield facility shall each month, starting in the facility's first year of commercial operation, file with the Commission, in such form as the Commission shall require, a report as to the consumer protection reserve account. The monthly report must contain the following information:

(A) the extent the monthly delivered SNG price is greater than, less than, or equal to the Chicago City-gate price;

(B) the amount credited or debited to the consumer protection reserve account during the month;

(C) the amounts credited to consumers and distributed to the clean coal SNG brownfield facility during the month;

(D) the total amount of the consumer protection reserve account at the beginning and end of the month;

(E) the total amount of consumer savings to date;

(F) a confidential summary of the inputs used to calculate the additional net revenue; and

(G) any other additional information the Commission shall require.

When any report is erroneous or defective or appears to the Commission to be erroneous or defective, the Commission may notify the clean coal SNG brownfield facility to amend the report within 30 days, and, before or after the termination of the 30-day period, the Commission may examine the trustee of the consumer protection reserve account or the officers, agents, employees, books, records, or accounts of the clean coal SNG brownfield facility and correct such items in the report as upon such examination the Commission may find defective or erroneous. All reports shall be under oath.

All reports made to the Commission by the clean coal SNG brownfield facility and the contents of the reports shall be open to public inspection and shall be deemed a public record under the Freedom of Information Act. Such reports shall be preserved in the office of the Commission. The Commission shall publish an annual summary of the reports prior to February 1 of the following year. The annual summary shall be made available to the public on the Commission's website and shall be submitted to the General Assembly.

Any facility that fails to file a report required under this paragraph (8) to the Commission within the time specified or to make specific answer to any question propounded by the Commission within 30 days from the time it is lawfully required to do so, or within such further time not to exceed 90 days as may in its discretion be allowed by the Commission, shall pay a penalty of $500 to the Commission for each day it is in default.

Any person who willfully makes any false report to the Commission or to any member, officer, or employee thereof, any person who willfully in a report withholds or fails to provide material information to which the Commission is entitled under this paragraph (8) and which information is either required to be filed by statute, rule, regulation, order, or decision of the Commission or has been requested by the Commission, and any person who willfully aids or abets such person shall be guilty of a Class A misdemeanor.

(h-3) Recoverable costs and revenue by the clean coal SNG brownfield facility.

(1) A capital recovery charge approved by the Commission shall be recoverable by the clean coal SNG brownfield facility under a sourcing agreement. The capital recovery charge shall be comprised of capital costs and a reasonable rate of return. "Capital costs" means costs to be incurred in connection with the construction and development of a facility, as defined in Section 1-10 of the Illinois Power Agency Act, and such other costs as the Capital Development Board deems appropriate to be recovered in the capital recovery charge.

(A) Capital costs. The Capital Development Board shall calculate a range of capital costs that it believes would be reasonable for the clean coal SNG brownfield facility to recover under the sourcing agreement. In making this determination, the Capital Development Board shall review the facility cost report, if any, of the clean coal SNG brownfield facility, adjusting the results based on the change in the Annual Consumer Price Index for All Urban Consumers for the Midwest Region as published in April by the United States Department of Labor, Bureau of Labor Statistics, the final draft of the sourcing agreement, and the rate of return approved by the Commission. In addition, the Capital Development Board may consult as much as it deems necessary with the clean coal SNG brownfield facility and conduct whatever research and investigation it deems necessary.

The Capital Development Board shall retain an engineering expert to assist in determining both the range of capital costs and the range of operations and maintenance costs that it believes would be reasonable for the clean coal SNG brownfield facility to recover under the sourcing agreement. Provided, however, that such expert shall: (i) not have been involved in the clean coal SNG brownfield facility's facility cost report, if any, (ii) not own or control any direct or indirect interest in the initial clean coal facility, and (iii) have no contractual relationship with the clean coal SNG brownfield facility. In order to qualify as an independent expert, a person or company must have:

(i) direct previous experience conducting front-end engineering and design studies for large-scale energy facilities and administering large-scale energy operations and maintenance contracts, which may be particularized to the specific type of financing associated with the clean coal SNG brownfield facility;

(ii) an advanced degree in economics, mathematics, engineering, or a related area of study;

(iii) ten years of experience in the energy sector, including construction and risk management experience;

(iv) expertise in assisting companies with obtaining financing for large-scale energy projects, which may be particularized to the specific type of financing associated with the clean coal SNG brownfield facility;

(v) expertise in operations and maintenance which may be particularized to the specific type of operations and maintenance associated with the clean coal SNG brownfield facility;

(vi) expertise in credit and contract protocols;

(vii) adequate resources to perform and fulfill the required functions and responsibilities; and

(viii) the absence of a conflict of interest and inappropriate bias for or against an affected gas utility or the clean coal SNG brownfield facility.

The clean coal SNG brownfield facility and the Illinois Power Agency shall cooperate with the Capital Development Board in any investigation it deems necessary. The Capital Development Board shall make its final determination of the range of capital costs confidentially and shall submit that range to the Commission in a confidential filing within 120 days after July 13, 2011 (the effective date of Public Act 97-096). The clean coal SNG brownfield facility shall submit to the Commission its estimate of the capital costs to be recovered under the sourcing agreement. Only after the clean coal SNG brownfield facility has submitted this estimate shall the Commission publicly announce the range of capital costs submitted by the Capital Development Board.

In the event that the estimate submitted by the clean coal SNG brownfield facility is within or below the range submitted by the Capital Development Board, the clean coal SNG brownfield facility's estimate shall be approved by the Commission as the amount of capital costs to be recovered under the sourcing agreement. In the event that the estimate submitted by the clean coal SNG brownfield facility is above the range submitted by the Capital Development Board, the amount of capital costs at the lowest end of the range submitted by the Capital Development Board shall be approved by the Commission as the amount of capital costs to be recovered under the sourcing agreement. Within 15 days after the Capital Development Board has submitted its range and the clean coal SNG brownfield facility has submitted its estimate, the Commission shall approve the capital costs for the clean coal SNG brownfield facility.

The Capital Development Board shall monitor the construction of the clean coal SNG brownfield facility for the full duration of construction to assess potential cost overruns. The Capital Development Board, in its discretion, may retain an expert to facilitate such monitoring. The clean coal SNG brownfield facility shall pay a reasonable fee as required by the Capital Development Board for the Capital Development Board's services under this subsection (h-3) to be deposited into the Capital Development Board Revolving Fund, and such fee shall not be passed through to a utility or its customers. If an expert is retained by the Capital Development Board for monitoring of construction, then the clean coal SNG brownfield facility must pay for the expert's reasonable fees and such costs shall not be passed through to a utility or its customers.

(B) Rate of Return. No later than 30 days after the date on which the Illinois Power Agency submits a final draft sourcing agreement, the Commission shall hold a public hearing to determine the rate of return to be recovered under the sourcing agreement. Rate of return shall be comprised of the clean coal SNG brownfield facility's actual cost of debt, including mortgage-style amortization, and a reasonable return on equity. The Commission shall post notice of the hearing on its website no later than 10 days prior to the date of the hearing. The Commission shall provide the public and all interested parties, including the gas utilities, the Attorney General, and the Illinois Power Agency, an opportunity to be heard.

In determining the return on equity, the Commission shall select a commercially reasonable return on equity taking into account the return on equity being received by developers of similar facilities in or outside of Illinois, the need to balance an incentive for clean-coal technology with the need to protect ratepayers from high gas prices, the risks being borne by the clean coal SNG brownfield facility in the final draft sourcing agreement, and any other information that the Commission may deem relevant. The Commission may establish a return on equity that varies with the amount of savings, if any, to customers during the term of the sourcing agreement, comparing the delivered SNG price to a daily weighted average price of natural gas, based upon an index. The Illinois Power Agency shall recommend a return on equity to the Commission using the same criteria. Within 60 days after receiving the final draft sourcing agreement from the Illinois Power Agency, the Commission shall approve the rate of return for the clean coal brownfield facility. Within 30 days after obtaining debt financing for the clean coal SNG brownfield facility, the clean coal SNG brownfield facility shall file a notice with the Commission identifying the actual cost of debt.

(2) Operations and maintenance costs approved by the Commission shall be recoverable by the clean coal SNG brownfield facility under the sourcing agreement. The operations and maintenance costs mean costs that have been incurred for the administration, supervision, operation, maintenance, preservation, and protection of the clean coal SNG brownfield facility's physical plant.

The Capital Development Board shall calculate a range of operations and maintenance costs that it believes would be reasonable for the clean coal SNG brownfield facility to recover under the sourcing agreement, incorporating an inflation index or combination of inflation indices to most accurately reflect the actual costs of operating the clean coal SNG brownfield facility. In making this determination, the Capital Development Board shall review the facility cost report, if any, of the clean coal SNG brownfield facility, adjusting the results for inflation based on the change in the Annual Consumer Price Index for All Urban Consumers for the Midwest Region as published in April by the United States Department of Labor, Bureau of Labor Statistics, the final draft of the sourcing agreement, and the rate of return approved by the Commission. In addition, the Capital Development Board may consult as much as it deems necessary with the clean coal SNG brownfield facility and conduct whatever research and investigation it deems necessary. As set forth in subparagraph (A) of paragraph (1) of this subsection (h-3), the Capital Development Board shall retain an independent engineering expert to assist in determining both the range of operations and maintenance costs that it believes would be reasonable for the clean coal SNG brownfield facility to recover under the sourcing agreement. The clean coal SNG brownfield facility and the Illinois Power Agency shall cooperate with the Capital Development Board in any investigation it deems necessary. The Capital Development Board shall make its final determination of the range of operations and maintenance costs confidentially and shall submit that range to the Commission in a confidential filing within 120 days after July 13, 2011.

The clean coal SNG brownfield facility shall submit to the Commission its estimate of the operations and maintenance costs to be recovered under the sourcing agreement. Only after the clean coal SNG brownfield facility has submitted this estimate shall the Commission publicly announce the range of operations and maintenance costs submitted by the Capital Development Board. In the event that the estimate submitted by the clean coal SNG brownfield facility is within or below the range submitted by the Capital Development Board, the clean coal SNG brownfield facility's estimate shall be approved by the Commission as the amount of operations and maintenance costs to be recovered under the sourcing agreement. In the event that the estimate submitted by the clean coal SNG brownfield facility is above the range submitted by the Capital Development Board, the amount of operations and maintenance costs at the lowest end of the range submitted by the Capital Development Board shall be approved by the Commission as the amount of operations and maintenance costs to be recovered under the sourcing agreement. Within 15 days after the Capital Development Board has submitted its range and the clean coal SNG brownfield facility has submitted its estimate, the Commission shall approve the operations and maintenance costs for the clean coal SNG brownfield facility.

The clean coal SNG brownfield facility shall pay for the independent engineering expert's reasonable fees and such costs shall not be passed through to a utility or its customers. The clean coal SNG brownfield facility shall pay a reasonable fee as required by the Capital Development Board for the Capital Development Board's services under this subsection (h-3) to be deposited into the Capital Development Board Revolving Fund, and such fee shall not be passed through to a utility or its customers.

(3) Sequestration costs approved by the Commission shall be recoverable by the clean coal SNG brownfield facility. "Sequestration costs" means costs to be incurred by the clean coal SNG brownfield facility in accordance with its Commission-approved carbon capture and sequestration plan to:

(A) capture carbon dioxide;

(B) build, operate, and maintain a sequestration site in which carbon dioxide may be injected;

(C) build, operate, and maintain a carbon dioxide pipeline; and

(D) transport the carbon dioxide to the sequestration site or a pipeline.

The Commission shall assess the prudency of the sequestration costs for the clean coal SNG brownfield facility before construction commences at the sequestration site or pipeline. Any revenues the clean coal SNG brownfield facility receives as a result of the capture, transportation, or sequestration of carbon dioxide shall be first credited against all sequestration costs, with the positive balance, if any, treated as additional net revenue.

The Commission may, in its discretion, retain an expert to assist in its review of sequestration costs. The clean coal SNG brownfield facility shall pay for the expert's reasonable fees if an expert is retained by the Commission, and such costs shall not be passed through to a utility or its customers. Once made, the Commission's determination of the amount of recoverable sequestration costs shall not be increased unless the clean coal SNG brownfield facility can show by clear and convincing evidence that (i) the costs were not reasonably foreseeable; (ii) the costs were due to circumstances beyond the clean coal SNG brownfield facility's control; and (iii) the clean coal SNG brownfield facility took all reasonable steps to mitigate the costs. If the Commission determines that sequestration costs may be increased, the Commission shall provide for notice and a public hearing for approval of the increased sequestration costs.

(4) Actual delivered and processed fuel costs shall be set by the Illinois Power Agency through a SNG feedstock procurement, pursuant to Sections 1-20, 1-77, and 1-78 of the Illinois Power Agency Act, to be performed at least every 5 years and purchased by the clean coal SNG brownfield facility pursuant to feedstock procurement contracts developed by the Illinois Power Agency, with coal comprising at least 50% of the total feedstock over the term of the sourcing agreement and petroleum coke comprising the remainder of the SNG feedstock. If the Commission fails to approve a feedstock procurement plan or fails to approve the results of a feedstock procurement event, then the fuel shall be purchased by the company month-by-month on the spot market and those actual delivered and processed fuel costs shall be recoverable under the sourcing agreement. If a supplier defaults under the terms of a procurement contract, then the Illinois Power Agency shall immediately initiate a feedstock procurement process to obtain a replacement supply, and, prior to the conclusion of that process, fuel shall be purchased by the company month-by-month on the spot market and those actual delivered and processed fuel costs shall be recoverable under the sourcing agreement.

(5) Taxes and fees imposed by the federal government, the State, or any unit of local government applicable to the clean coal SNG brownfield facility, excluding income tax, shall be recoverable by the clean coal SNG brownfield facility under the sourcing agreement to the extent such taxes and fees were not applicable to the facility on July 13, 2011.

(6) The actual transportation costs, in accordance with the applicable utility's tariffs, and third-party marketer costs incurred by the company, if any, associated with transporting the SNG from the clean coal SNG brownfield facility to the Chicago City-gate to sell such SNG into the natural gas markets shall be recoverable under the sourcing agreement.

(7) Unless otherwise provided, within 30 days after a decision of the Commission on recoverable costs under this Section, any interested party to the Commission's decision may apply for a rehearing with respect to the decision. The Commission shall receive and consider the application for rehearing and shall grant or deny the application in whole or in part within 20 days after the date of the receipt of the application by the Commission. If no rehearing is applied for within the required 30 days or an application for rehearing is denied, then the Commission decision shall be final. If an application for rehearing is granted, then the Commission shall hold a rehearing within 30 days after granting the application. The decision of the Commission upon rehearing shall be final.

Any person affected by a decision of the Commission under this subsection (h-3) may have the decision reviewed only under and in accordance with the Administrative Review Law. Unless otherwise provided, the provisions of the Administrative Review Law, all amendments and modifications to that Law, and the rules adopted pursuant to that Law shall apply to and govern all proceedings for the judicial review of final administrative decisions of the Commission under this subsection (h-3). The term "administrative decision" is defined as in Section 3-101 of the Code of Civil Procedure.

(8) The Capital Development Board shall adopt and make public a policy detailing the process for retaining experts under this Section. Any experts retained to assist with calculating the range of capital costs or operations and maintenance costs shall be retained no later than 45 days after July 13, 2011.

(h-4) No later than 90 days after the Illinois Power Agency submits the final draft sourcing agreement pursuant to subsection (h-1), the Commission shall approve a sourcing agreement containing (i) the capital costs, rate of return, and operations and maintenance costs established pursuant to subsection (h-3) and (ii) all other terms and conditions, rights, provisions, exceptions, and limitations contained in the final draft sourcing agreement; provided, however, the Commission shall correct typographical and scrivener's errors and modify the contract only as necessary to provide that the gas utility does not have the right to terminate the sourcing agreement due to any future events that may occur other than the clean coal SNG brownfield facility's failure to timely meet milestones, uncured default, extended force majeure, or abandonment. Once the sourcing agreement is approved, then the gas utility subject to that sourcing agreement shall have 45 days after the date of the Commission's approval to enter into the sourcing agreement.

(h-5) Sequestration enforcement.

(A) All contracts entered into under subsection (h) of this Section and all sourcing agreements under subsection (h-1) of this Section, regardless of duration, shall require the owner of any facility supplying SNG under the contract or sourcing agreement to provide certified documentation to the Commission each year, starting in the facility's first year of commercial operation, accurately reporting the quantity of carbon dioxide emissions from the facility that have been captured and sequestered and reporting any quantities of carbon dioxide released from the site or sites at which carbon dioxide emissions were sequestered in prior years, based on continuous monitoring of those sites.

(B) If, in any year, the owner of the clean coal SNG facility fails to demonstrate that the SNG facility captured and sequestered at least 90% of the total carbon dioxide emissions that the facility would otherwise emit or that sequestration of emissions from prior years has failed, resulting in the release of carbon dioxide into the atmosphere, then the owner of the clean coal SNG facility must pay a penalty of $20 per ton of excess carbon dioxide emissions not to exceed $40,000,000, in any given year which shall be deposited into the Energy Efficiency Trust Fund and distributed pursuant to subsection (b) of Section 6-6 of the Renewable Energy, Energy Efficiency, and Coal Resources Development Law of 1997. On or before the 5-year anniversary of the execution of the contract and every 5 years thereafter, an expert hired by the owner of the facility with the approval of the Attorney General shall conduct an analysis to determine the cost of sequestration of at least 90% of the total carbon dioxide emissions the plant would otherwise emit. If the analysis shows that the actual annual cost is greater than the penalty, then the penalty shall be increased to equal the actual cost. Provided, however, to the extent that the owner of the facility described in subsection (h) of this Section can demonstrate that the failure was as a result of acts of God (including fire, flood, earthquake, tornado, lightning, hurricane, or other natural disaster); any amendment, modification, or abrogation of any applicable law or regulation that would prevent performance; war; invasion; act of foreign enemies; hostilities (regardless of whether war is declared); civil war; rebellion; revolution; insurrection; military or usurped power or confiscation; terrorist activities; civil disturbance; riots; nationalization; sabotage; blockage; or embargo, the owner of the facility described in subsection (h) of this Section shall not be subject to a penalty if and only if (i) it promptly provides notice of its failure to the Commission; (ii) as soon as practicable and consistent with any order or direction from the Commission, it submits to the Commission proposed modifications to its carbon capture and sequestration plan; and (iii) it carries out its proposed modifications in the manner and time directed by the Commission.

If the Commission finds that the facility has not satisfied each of these requirements, then the facility shall be subject to the penalty. If the owner of the clean coal SNG facility captured and sequestered more than 90% of the total carbon dioxide emissions that the facility would otherwise emit, then the owner of the facility may credit such additional amounts to reduce the amount of any future penalty to be paid. The penalty resulting from the failure to capture and sequester at least the minimum amount of carbon dioxide shall not be passed on to a utility or its customers.

If the clean coal SNG facility fails to meet the requirements specified in this subsection (h-5), then the Attorney General, on behalf of the People of the State of Illinois, shall bring an action to enforce the obligations related to the facility set forth in this subsection (h-5), including any penalty payments owed, but not including the physical obligation to capture and sequester at least 90% of the total carbon dioxide emissions that the facility would otherwise emit. Such action may be filed in any circuit court in Illinois. By entering into a contract pursuant to subsection (h) of this Section, the clean coal SNG facility agrees to waive any objections to venue or to the jurisdiction of the court with regard to the Attorney General's action under this subsection (h-5).

Compliance with the sequestration requirements and any penalty requirements specified in this subsection (h-5) for the clean coal SNG facility shall be assessed annually by the Commission, which may in its discretion retain an expert to facilitate its assessment. If any expert is retained by the Commission, then the clean coal SNG facility shall pay for the expert's reasonable fees, and such costs shall not be passed through to the utility or its customers.

In addition, carbon dioxide emission credits received by the clean coal SNG facility in connection with sequestration of carbon dioxide from the facility must be sold in a timely fashion with any revenue, less applicable fees and expenses and any expenses required to be paid by facility for carbon dioxide transportation or sequestration, deposited into the reconciliation account within 30 days after receipt of such funds by the owner of the clean coal SNG facility.

The clean coal SNG facility is prohibited from transporting or sequestering carbon dioxide unless the owner of the carbon dioxide pipeline that transfers the carbon dioxide from the facility and the owner of the sequestration site where the carbon dioxide captured by the facility is stored has acquired all applicable permits under applicable State and federal laws, statutes, rules, or regulations prior to the transfer or sequestration of carbon dioxide. The responsibility for compliance with the sequestration requirements specified in this subsection (h-5) for the clean coal SNG facility shall reside solely with the clean coal SNG facility, regardless of whether the facility has contracted with another party to capture, transport, or sequester carbon dioxide.

(C) If, in any year, the owner of a clean coal SNG brownfield facility fails to demonstrate that the clean coal SNG brownfield facility captured and sequestered at least 85% of the total carbon dioxide emissions that the facility would otherwise emit, then the owner of the clean coal SNG brownfield facility must pay a penalty of $20 per ton of excess carbon emissions up to $20,000,000, which shall be deposited into the Energy Efficiency Trust Fund and distributed pursuant to subsection (b) of Section 6-6 of the Renewable Energy, Energy Efficiency, and Coal Resources Development Law of 1997. Provided, however, to the extent that the owner of the clean coal SNG brownfield facility can demonstrate that the failure was as a result of acts of God (including fire, flood, earthquake, tornado, lightning, hurricane, or other natural disaster); any amendment, modification, or abrogation of any applicable law or regulation that would prevent performance; war; invasion; act of foreign enemies; hostilities (regardless of whether war is declared); civil war; rebellion; revolution; insurrection; military or usurped power or confiscation; terrorist activities; civil disturbances; riots; nationalization; sabotage; blockage; or embargo, the owner of the clean coal SNG brownfield facility shall not be subject to a penalty if and only if (i) it promptly provides notice of its failure to the Commission; (ii) as soon as practicable and consistent with any order or direction from the Commission, it submits to the Commission proposed modifications to its carbon capture and sequestration plan; and (iii) it carries out its proposed modifications in the manner and time directed by the Commission. If the Commission finds that the facility has not satisfied each of these requirements, then the facility shall be subject to the penalty. If the owner of a clean coal SNG brownfield facility demonstrates that the clean coal SNG brownfield facility captured and sequestered more than 85% of the total carbon emissions that the facility would otherwise emit, the owner of the clean coal SNG brownfield facility may credit such additional amounts to reduce the amount of any future penalty to be paid. The penalty resulting from the failure to capture and sequester at least the minimum amount of carbon dioxide shall not be passed on to a utility or its customers.

In addition to any penalty for the clean coal SNG brownfield facility's failure to capture and sequester at least its minimum sequestration requirement, the Attorney General, on behalf of the People of the State of Illinois, shall bring an action for specific performance of this subsection (h-5). Such action may be filed in any circuit court in Illinois. By entering into a sourcing agreement pursuant to subsection (h-1) of this Section, the clean coal SNG brownfield facility agrees to waive any objections to venue or to the jurisdiction of the court with regard to the Attorney General's action for specific performance under this subsection (h-5).

Compliance with the sequestration requirements and penalty requirements specified in this subsection (h-5) for the clean coal SNG brownfield facility shall be assessed annually by the Commission, which may in its discretion retain an expert to facilitate its assessment. If an expert is retained by the Commission, then the clean coal SNG brownfield facility shall pay for the expert's reasonable fees, and such costs shall not be passed through to a utility or its customers. A SNG facility operating pursuant to this subsection (h-5) shall not forfeit its designation as a clean coal SNG facility or a clean coal SNG brownfield facility if the facility fails to fully comply with the applicable carbon sequestration requirements in any given year, provided the requisite offsets are purchased or requisite penalties are paid.

Responsibility for compliance with the sequestration requirements specified in this subsection (h-5) for the clean coal SNG brownfield facility shall reside solely with the clean coal SNG brownfield facility regardless of whether the facility has contracted with another party to capture, transport, or sequester carbon dioxide.

(h-7) Sequestration permitting, oversight, and investigations.

(1) No clean coal facility or clean coal SNG brownfield facility may transport or sequester carbon dioxide unless the Commission approves the method of carbon dioxide transportation or sequestration. Such approval shall be required regardless of whether the facility has contracted with another to transport or sequester the carbon dioxide. Nothing in this subsection (h-7) shall release the owner or operator of a carbon dioxide sequestration site or carbon dioxide pipeline from any other permitting requirements under applicable State and federal laws, statutes, rules, or regulations.

(2) The Commission shall review carbon dioxide transportation and sequestration methods proposed by a clean coal facility or a clean coal SNG brownfield facility and shall approve those methods it deems reasonable and cost-effective. For purposes of this review, "cost-effective" means a commercially reasonable price for similar carbon dioxide transportation or sequestration techniques. In determining whether sequestration is reasonable and cost-effective, the Commission may consult with the Illinois State Geological Survey and retain third parties to assist in its determination, provided that such third parties shall not own or control any direct or indirect interest in the facility that is proposing the carbon dioxide transportation or the carbon dioxide sequestration method and shall have no contractual relationship with that facility. If a third party is retained by the Commission, then the facility proposing the carbon dioxide transportation or sequestration method shall pay for the expert's reasonable fees, and these costs shall not be passed through to a utility or its customers.

No later than 6 months prior to the date upon which the owner intends to commence construction of a clean coal facility or the clean coal SNG brownfield facility, the owner of the facility shall file with the Commission a carbon dioxide transportation or sequestration plan. The Commission shall hold a public hearing within 30 days after receipt of the facility's carbon dioxide transportation or sequestration plan. The Commission shall post notice of the review on its website upon submission of a carbon dioxide transportation or sequestration method and shall accept written public comments. The Commission shall take the comments into account when making its decision.

The Commission may not approve a carbon dioxide sequestration method if the owner or operator of the sequestration site has not received (i) an Underground Injection Control permit from the United States Environmental Protection Agency, or from the Illinois Environmental Protection Agency pursuant to the Environmental Protection Act; (ii) an Underground Injection Control permit from the Illinois Department of Natural Resources pursuant to the Illinois Oil and Gas Act; or (iii) an Underground Injection Control permit from the United States Environmental Protection Agency or a permit similar to items (i) or (ii) from the state in which the sequestration site is located if the sequestration will take place outside of Illinois. The Commission shall approve or deny the carbon dioxide transportation or sequestration method within 90 days after the receipt of all required information.

(3) At least annually, the Illinois Environmental Protection Agency shall inspect all carbon dioxide sequestration sites in Illinois. The Illinois Environmental Protection Agency may, as often as deemed necessary, monitor and conduct investigations of those sites. The owner or operator of the sequestration site must cooperate with the Illinois Environmental Protection Agency investigations of carbon dioxide sequestration sites.

If the Illinois Environmental Protection Agency determines at any time a site creates conditions that warrant the issuance of a seal order under Section 34 of the Environmental Protection Act, then the Illinois Environmental Protection Agency shall seal the site pursuant to the Environmental Protection Act. If the Illinois Environmental Protection Agency determines at any time a carbon dioxide sequestration site creates conditions that warrant the institution of a civil action for an injunction under Section 43 of the Environmental Protection Act, then the Illinois Environmental Protection Agency shall request the State's Attorney or the Attorney General institute such action. The Illinois Environmental Protection Agency shall provide notice of any such actions as soon as possible on its website. The SNG facility shall incur all reasonable costs associated with any such inspection or monitoring of the sequestration sites, and these costs shall not be recoverable from utilities or their customers.

(4) (Blank).

(h-9) The clean coal SNG brownfield facility shall have the right to recover prudently incurred increased costs or reduced revenue resulting from any new or amendatory legislation or other action. The State of Illinois pledges that the State will not enact any law or take any action to:

(1) break, or repeal the authority for, sourcing agreements approved by the Commission and entered into between public utilities and the clean coal SNG brownfield facility;

(2) deny public utilities full cost recovery for their costs incurred under those sourcing agreements; or

(3) deny the clean coal SNG brownfield facility full cost and revenue recovery as provided under those sourcing agreements that are recoverable pursuant to subsection (h-3) of this Section.

These pledges are for the benefit of the parties to those sourcing agreements and the issuers and holders of bonds or other obligations issued or incurred to finance or refinance the clean coal SNG brownfield facility. The clean coal SNG brownfield facility is authorized to include and refer to these pledges in any financing agreement into which it may enter in regard to those sourcing agreements.

The State of Illinois retains and reserves all other rights to enact new or amendatory legislation or take any other action, without impairment of the right of the clean coal SNG brownfield facility to recover prudently incurred increased costs or reduced revenue resulting from the new or amendatory legislation or other action, including, but not limited to, such legislation or other action that would (i) directly or indirectly raise the costs the clean coal SNG brownfield facility must incur; (ii) directly or indirectly place additional restrictions, regulations, or requirements on the clean coal SNG brownfield facility; (iii) prohibit sequestration in general or prohibit a specific sequestration method or project; or (iv) increase minimum sequestration requirements for the clean coal SNG brownfield facility to the extent technically feasible. The clean coal SNG brownfield facility shall have the right to recover prudently incurred increased costs or reduced revenue resulting from the new or amendatory legislation or other action as described in this subsection (h-9).

(h-10) Contract costs for SNG incurred by an Illinois gas utility are reasonable and prudent and recoverable through the purchased gas adjustment clause and are not subject to review or disallowance by the Commission. Contract costs are costs incurred by the utility under the terms of a contract that incorporates the terms stated in subsection (h) of this Section as confirmed in writing by the Illinois Power Agency as set forth in subsection (h) of this Section, which confirmation shall be deemed conclusive, or as a consequence of or condition to its performance under the contract, including (i) amounts paid for SNG under the SNG contract and (ii) costs of transportation and storage services of SNG purchased from interstate pipelines under federally approved tariffs. The Illinois gas utility shall initiate a clean coal SNG facility rider mechanism that (A) shall be applicable to all customers who receive transportation service from the utility, (B) shall be designed to have an equal percentage impact on the transportation services rates of each class of the utility's total customers, and (C) shall accurately reflect the net customer savings, if any, and above market costs, if any, under the SNG contract. Any contract, the terms of which have been confirmed in writing by the Illinois Power Agency as set forth in subsection (h) of this Section and the performance of the parties under such contract cannot be grounds for challenging prudence or cost recovery by the utility through the purchased gas adjustment clause, and in such cases, the Commission is directed not to consider, and has no authority to consider, any attempted challenges.

The contracts entered into by Illinois gas utilities pursuant to subsection (h) of this Section shall provide that the utility retains the right to terminate the contract without further obligation or liability to any party if the contract has been impaired as a result of any legislative, administrative, judicial, or other governmental action that is taken that eliminates all or part of the prudence protection of this subsection (h-10) or denies the recoverability of all or part of the contract costs through the purchased gas adjustment clause. Should any Illinois gas utility exercise its right under this subsection (h-10) to terminate the contract, all contract costs incurred prior to termination are and will be deemed reasonable, prudent, and recoverable as and when incurred and not subject to review or disallowance by the Commission. Any order, issued by the State requiring or authorizing the discontinuation of the merchant function, defined as the purchase and sale of natural gas by an Illinois gas utility for the ultimate consumer in its service territory shall include provisions necessary to prevent the impairment of the value of any contract hereunder over its full term.

(h-11) All costs incurred by an Illinois gas utility in procuring SNG from a clean coal SNG brownfield facility pursuant to subsection (h-1) or a third-party marketer pursuant to subsection (h-1) are reasonable and prudent and recoverable through the purchased gas adjustment clause in conjunction with a SNG brownfield facility rider mechanism and are not subject to review or disallowance by the Commission; provided that if a utility is required by law or otherwise elects to connect the clean coal SNG brownfield facility to an interstate pipeline, then the utility shall be entitled to recover pursuant to its tariffs all just and reasonable costs that are prudently incurred. Sourcing agreement costs are costs incurred by the utility under the terms of a sourcing agreement that incorporates the terms stated in subsection (h-1) of this Section as approved by the Commission as set forth in subsection (h-4) of this Section, which approval shall be deemed conclusive, or as a consequence of or condition to its performance under the contract, including (i) amounts paid for SNG under the SNG contract and (ii) costs of transportation and storage services of SNG purchased from interstate pipelines under federally approved tariffs. Any sourcing agreement, the terms of which have been approved by the Commission as set forth in subsection (h-4) of this Section, and the performance of the parties under the sourcing agreement cannot be grounds for challenging prudence or cost recovery by the utility, and in these cases, the Commission is directed not to consider, and has no authority to consider, any attempted challenges.

(h-15) Reconciliation account. The clean coal SNG facility shall establish a reconciliation account for the benefit of the retail customers of the utilities that have entered into contracts with the clean coal SNG facility pursuant to subsection (h). The reconciliation account shall be maintained and administered by an independent trustee that is mutually agreed upon by the owners of the clean coal SNG facility, the utilities, and the Commission in an interest-bearing account in accordance with the following:

(1) The clean coal SNG facility shall conduct an analysis annually within 60 days after receiving the necessary cost information, which shall be provided by the gas utility within 6 months after the end of the preceding calendar year, to determine (i) the average annual contract SNG cost, which shall be calculated as the total amount paid for SNG purchased from the clean coal SNG facility over the preceding 12 months, plus the cost to the utility of the required transportation and storage services of SNG, divided by the total number of MMBtus of SNG actually purchased from the clean coal SNG facility in the preceding 12 months under the utility contract; (ii) the average annual natural gas purchase cost, which shall be calculated as the total annual supply costs paid for baseload natural gas (excluding any SNG) purchased by such utility over the preceding 12 months plus the costs of transportation and storage services of such natural gas (excluding such costs for SNG), divided by the total number of MMbtus of baseload natural gas (excluding SNG) actually purchased by the utility during the year; (iii) the cost differential, which shall be the difference between the average annual contract SNG cost and the average annual natural gas purchase cost; and (iv) the revenue share target which shall be the cost differential multiplied by the total amount of SNG purchased over the preceding 12 months under such utility contract.

(A) To the extent the annual average contract SNG cost is less than the annual average natural gas purchase cost, the utility shall credit an amount equal to the revenue share target to the reconciliation account. Such credit payment shall be made monthly starting within 30 days after the completed analysis in this subsection (h-15) and based on collections from all customers via a line item charge in all customer bills designed to have an equal percentage impact on the transportation services of each class of customers. Credit payments made pursuant to this subparagraph (A) shall be deemed prudent and reasonable and not subject to Commission prudence review.

(B) To the extent the annual average contract SNG cost is greater than the annual average natural gas purchase cost, the reconciliation account shall be used to provide a credit equal to the revenue share target to the utilities to be used to reduce the utility's natural gas costs through the purchased gas adjustment clause. Such payment shall be made within 30 days after the completed analysis pursuant to this subsection (h-15), but only to the extent that the reconciliation account has a positive balance.

(2) At the conclusion of the term of the SNG contracts pursuant to subsection (h) and the completion of the final annual analysis pursuant to this subsection (h-15), to the extent the facility owes any amount to retail customers, amounts in the account shall be credited to retail customers to the extent the owed amount is repaid; 50% of any additional amount in the reconciliation account shall be distributed to the utilities to be used to reduce the utilities' natural gas costs through the purchase gas adjustment clause with the remaining amount distributed to the clean coal SNG facility. Such payment shall be made within 30 days after the last completed analysis pursuant to this subsection (h-15). If the facility has repaid all owed amounts, if any, to retail customers and has distributed 50% of any additional amount in the account to the utilities, then the owners of the clean coal SNG facility shall have no further obligation to the utility or the retail customers.

If, at the conclusion of the term of the contracts pursuant to subsection (h) and the completion of the final annual analysis pursuant to this subsection (h-15), the facility owes any amount to retail customers and the account has been depleted, then the clean coal SNG facility shall be liable for any remaining amount owed to the retail customers. The clean coal SNG facility shall market the daily production of SNG and distribute on a monthly basis 5% of the amounts collected with respect to such future sales to the utilities in proportion to each utility's SNG contract to be used to reduce the utility's natural gas costs through the purchase gas adjustment clause; such payments to the utility shall continue until either 15 years after the conclusion of the contract or such time as the sum of such payments equals the remaining amount owed to the retail customers at the end of the contract, whichever is earlier. If the debt to the retail customers is not repaid within 15 years after the conclusion of the contract, then the owner of the clean coal SNG facility must sell the facility, and all proceeds from that sale must be used to repay any amount owed to the retail customers under this subsection (h-15).

The retail customers shall have first priority in recovering that debt above any creditors, except the secured lenders to the extent that the secured lenders have any secured debt outstanding, including any parent companies or affiliates of the clean coal SNG facility.

(3) 50% of all additional net revenue, defined as miscellaneous net revenue after cost allowance and above the budgeted estimate established for revenue pursuant to subsection (h), including sale of substitute natural gas derived from the clean coal SNG facility above the nameplate capacity of the facility and other by-products produced by the facility, shall be credited to the reconciliation account on an annual basis with such payment made within 30 days after the end of each calendar year during the term of the contract.

(4) The clean coal SNG facility shall each year, starting in the facility's first year of commercial operation, file with the Commission, in such form as the Commission shall require, a report as to the reconciliation account. The annual report must contain the following information:

(A) the revenue share target amount;

(B) the amount credited or debited to the reconciliation account during the year;

(C) the amount credited to the utilities to be used to reduce the utilities natural gas costs though the purchase gas adjustment clause;

(D) the total amount of reconciliation account at the beginning and end of the year;

(E) the total amount of consumer savings to date; and

(F) any additional information the Commission may require.

When any report is erroneous or defective or appears to the Commission to be erroneous or defective, the Commission may notify the clean coal SNG facility to amend the report within 30 days; before or after the termination of the 30-day period, the Commission may examine the trustee of the reconciliation account or the officers, agents, employees, books, records, or accounts of the clean coal SNG facility and correct such items in the report as upon such examination the Commission may find defective or erroneous. All reports shall be under oath.

All reports made to the Commission by the clean coal SNG facility and the contents of the reports shall be open to public inspection and shall be deemed a public record under the Freedom of Information Act. Such reports shall be preserved in the office of the Commission. The Commission shall publish an annual summary of the reports prior to February 1 of the following year. The annual summary shall be made available to the public on the Commission's website and shall be submitted to the General Assembly.

Any facility that fails to file the report required under this paragraph (4) to the Commission within the time specified or to make specific answer to any question propounded by the Commission within 30 days after the time it is lawfully required to do so, or within such further time not to exceed 90 days as may be allowed by the Commission in its discretion, shall pay a penalty of $500 to the Commission for each day it is in default.

Any person who willfully makes any false report to the Commission or to any member, officer, or employee thereof, any person who willfully in a report withholds or fails to provide material information to which the Commission is entitled under this paragraph (4) and which information is either required to be filed by statute, rule, regulation, order, or decision of the Commission or has been requested by the Commission, and any person who willfully aids or abets such person shall be guilty of a Class A misdemeanor.

(h-20) The General Assembly authorizes the Illinois Finance Authority to issue bonds to the maximum extent permitted to finance coal gasification facilities described in this Section, which constitute both "industrial projects" under Article 801 of the Illinois Finance Authority Act and "clean coal and energy projects" under Sections 825-65 through 825-75 of the Illinois Finance Authority Act.

Administrative costs incurred by the Illinois Finance Authority in performance of this subsection (h-20) shall be subject to reimbursement by the clean coal SNG facility on terms as the Illinois Finance Authority and the clean coal SNG facility may agree. The utility and its customers shall have no obligation to reimburse the clean coal SNG facility or the Illinois Finance Authority for any such costs.

(h-25) The State of Illinois pledges that the State may not enact any law or take any action to (1) break or repeal the authority for SNG purchase contracts entered into between public gas utilities and the clean coal SNG facility pursuant to subsection (h) of this Section or (2) deny public gas utilities their full cost recovery for contract costs, as defined in subsection (h-10), that are incurred under such SNG purchase contracts. These pledges are for the benefit of the parties to such SNG purchase contracts and the issuers and holders of bonds or other obligations issued or incurred to finance or refinance the clean coal SNG facility. The beneficiaries are authorized to include and refer to these pledges in any finance agreement into which they may enter in regard to such contracts.

(h-30) The State of Illinois retains and reserves all other rights to enact new or amendatory legislation or take any other action, including, but not limited to, such legislation or other action that would (1) directly or indirectly raise the costs that the clean coal SNG facility must incur; (2) directly or indirectly place additional restrictions, regulations, or requirements on the clean coal SNG facility; (3) prohibit sequestration in general or prohibit a specific sequestration method or project; or (4) increase minimum sequestration requirements.

(i) If a gas utility or an affiliate of a gas utility has an ownership interest in any entity that produces or sells synthetic natural gas, Article VII of this Act shall apply.

(Source: P.A. 100-391, eff. 8-25-17.)

(220 ILCS 5/9-220.1) (from Ch. 111 2/3, par. 9-220.1)

Sec. 9-220.1. Environmental fees - modification of rates and charges. Any electric public utility may file a separate tariff designed to recover the fees paid under subsection 18 of Section 39.5 of the Environmental Protection Act as they are incurred, independent of any other matters related to its revenue requirements. Annually, the Commission shall initiate hearings to reconcile amounts collected under the tariff with the amounts properly disbursed by the utility under subsection 18 of Section 39.5 of the Environmental Protection Act.

(Source: P.A. 87-1213.)

(220 ILCS 5/9-220.2)

Sec. 9-220.2. Water and sewer surcharges authorized.

(a) The Commission may authorize a water or sewer utility to file a surcharge which adjusts rates and charges to provide for recovery of (i) the cost of purchased water, (ii) the cost of purchased sewage treatment service, (iii) other costs which fluctuate for reasons beyond the utility's control or are difficult to predict, or (iv) costs associated with an investment in qualifying infrastructure plant, independent of any other matters related to the utility's revenue requirement. A surcharge approved under this Section can operate on an historical or a prospective basis.

(b) For purposes of this Section, "costs associated with an investment in qualifying infrastructure plant" include a return on the investment in and depreciation expense related to plant items or facilities (including, but not limited to, replacement mains, meters, services, and hydrants) which (i) are not reflected in the rate base used to establish the utility's base rates and (ii) are non-revenue producing. For purposes of this Section, a "non-revenue producing facility" is one that is not constructed or installed for the purpose of serving a new customer.

(c) On a periodic basis, the Commission shall initiate hearings to reconcile amounts collected under each surcharge authorized pursuant to this Section with the actual prudently incurred costs recoverable for each annual period during which the surcharge was in effect.

(Source: P.A. 91-638, eff. 1-1-00.)

(220 ILCS 5/9-220.3)

Sec. 9-220.3. (Repealed).

(Source: P.A. 98-57, eff. 7-5-13. Repealed internally, eff. 12-31-23.)

(220 ILCS 5/9-221) (from Ch. 111 2/3, par. 9-221)

Sec. 9-221. Whenever a municipality pursuant to Section 8-11-2 of the Illinois Municipal Code, as heretofore and hereafter amended, imposes a tax on any public utility, such utility may charge its customers, other than customers who are certified business enterprises under paragraph (e) of Section 8-11-2 of the Illinois Municipal Code or are exempted from those taxes under paragraph (f) of that Section, to the extent of such exemption and during the period in which such exemption is in effect, in addition to any rate authorized by this Act, an additional charge equal to the sum of (1) an amount equal to such municipal tax, or any part thereof (2) 3% of such tax, or any part thereof, as the case may be, to cover costs of accounting, and (3) an amount equal to the increase in taxes and other payments to governmental bodies resulting from the amount of such additional charge. Such utility shall file with the Commission a true and correct copy of the municipal ordinance imposing such tax; and also shall file with the Commission a supplemental schedule applicable to such municipality which shall specify such additional charge and which shall become effective upon filing without further notice. Such additional charge shall be shown separately on the utility bill to each customer. The Commission shall have power to investigate whether or not such supplemental schedule correctly specifies such additional charge, but shall have no power to suspend such supplemental schedule. If the Commission finds, after a hearing, that such supplemental schedule does not correctly specify such additional charge, it shall by order require a refund to the appropriate customers of the excess, if any, with interest, in such manner as it shall deem just and reasonable, and in and by such order shall require the utility to file an amended supplemental schedule corresponding to the finding and order of the Commission.

(Source: P.A. 87-895; 88-132.)

(220 ILCS 5/9-222) (from Ch. 111 2/3, par. 9-222)

Sec. 9-222. Whenever a tax is imposed upon a public utility engaged in the business of distributing, supplying, furnishing, or selling gas for use or consumption pursuant to Section 2 of the Gas Revenue Tax Act, or whenever a tax is required to be collected by a delivering supplier pursuant to Section 2-7 of the Electricity Excise Tax Act, or whenever a tax is imposed upon a public utility pursuant to Section 2-202 of this Act, such utility may charge its customers, other than customers who are high impact businesses under Section 5.5 of the Illinois Enterprise Zone Act, customers who are certified under Section 95 of the Reimagining Energy and Vehicles in Illinois Act, manufacturers under the Manufacturing Illinois Chips for Real Opportunity (MICRO) Act, customers who are tenants in a quantum computing campus under Section 605-1115 of the Department of Commerce and Economic Opportunity Law of the Civil Administrative Code of Illinois, or certified business enterprises under Section 9-222.1 of this Act, to the extent of such exemption and during the period in which such exemption is in effect, in addition to any rate authorized by this Act, an additional charge equal to the total amount of such taxes. The exemption of this Section relating to high impact businesses shall be subject to the provisions of subsections (a), (b), and (b-5) of Section 5.5 of the Illinois Enterprise Zone Act. This requirement shall not apply to taxes on invested capital imposed pursuant to the Messages Tax Act, the Gas Revenue Tax Act and the Public Utilities Revenue Act. Such utility shall file with the Commission a supplemental schedule which shall specify such additional charge and which shall become effective upon filing without further notice. Such additional charge shall be shown separately on the utility bill to each customer. The Commission shall have the power to investigate whether or not such supplemental schedule correctly specifies such additional charge, but shall have no power to suspend such supplemental schedule. If the Commission finds, after a hearing, that such supplemental schedule does not correctly specify such additional charge, it shall by order require a refund to the appropriate customers of the excess, if any, with interest, in such manner as it shall deem just and reasonable, and in and by such order shall require the utility to file an amended supplemental schedule corresponding to the finding and order of the Commission. Except with respect to taxes imposed on invested capital, such tax liabilities shall be recovered from customers solely by means of the additional charges authorized by this Section.

(Source: P.A. 102-669, eff. 11-16-21; 102-700, eff. 4-19-22; 102-1125, eff. 2-3-23; 103-595, eff. 6-26-24.)

(220 ILCS 5/9-222.1) (from Ch. 111 2/3, par. 9-222.1)

Sec. 9-222.1. A business enterprise which is located within an area designated by a county or municipality as an enterprise zone pursuant to the Illinois Enterprise Zone Act or located in a federally designated Foreign Trade Zone or Sub-Zone shall be exempt from the additional charges added to the business enterprise's utility bills as a pass-on of municipal and State utility taxes under Sections 9-221 and 9-222 of this Act, to the extent such charges are exempted by ordinance adopted in accordance with paragraph (e) of Section 8-11-2 of the Illinois Municipal Code in the case of municipal utility taxes, and to the extent such charges are exempted by the percentage specified by the Department of Commerce and Economic Opportunity in the case of State utility taxes, provided such business enterprise meets the following criteria:

(1) it (i) makes investments which cause the creation of a minimum of 200 full-time equivalent jobs in Illinois; (ii) makes investments of at least $175,000,000 which cause the creation of a minimum of 150 full-time equivalent jobs in Illinois; (iii) makes investments that cause the retention of a minimum of 300 full-time equivalent jobs in the manufacturing sector, as defined by the North American Industry Classification System, in an area in Illinois in which the unemployment rate is above 9% and makes an application to the Department within 3 months after the effective date of this amendatory Act of the 96th General Assembly and certifies relocation of the 300 full-time equivalent jobs within 48 months after the application; (iv) makes investments which cause the retention of a minimum of 1,000 full-time jobs in Illinois; or (v) makes an application to the Department within 2 months after the effective date of this amendatory Act of the 96th General Assembly and makes investments that cause the retention of a minimum of 500 full-time equivalent jobs in 2009 and 2010, 675 full-time jobs in Illinois in 2011, 850 full-time jobs in 2012, and 750 full-time jobs per year in 2013 through 2017, in the manufacturing sector as defined by the North American Industry Classification System; and

(2) it is either (i) located in an Enterprise Zone established pursuant to the Illinois Enterprise Zone Act or (ii) located in a federally designated Foreign Trade Zone or Sub-Zone and is designated a High Impact Business by the Department of Commerce and Economic Opportunity; and

(3) it is certified by the Department of Commerce and Economic Opportunity as complying with the requirements specified in clauses (1) and (2) of this Section.

The Department of Commerce and Economic Opportunity shall determine the period during which such exemption from the charges imposed under Section 9-222 is in effect which shall not exceed 30 years or the certified term of the enterprise zone, whichever period is shorter, except that the exemption period for a business enterprise qualifying under item (iii) of clause (1) of this Section shall not exceed 30 years.

The Department of Commerce and Economic Opportunity shall have the power to promulgate rules and regulations to carry out the provisions of this Section including procedures for complying with the requirements specified in clauses (1) and (2) of this Section and procedures for applying for the exemptions authorized under this Section; to define the amounts and types of eligible investments which business enterprises must make in order to receive State utility tax exemptions pursuant to Sections 9-222 and 9-222.1 of this Act; to approve such utility tax exemptions for business enterprises whose investments are not yet placed in service; and to require that business enterprises granted tax exemptions repay the exempted tax should the business enterprise fail to comply with the terms and conditions of the certification. However, no business enterprise shall be required, as a condition for certification under clause (3) of this Section, to attest that its decision to invest under clause (1) of this Section and to locate under clause (2) of this Section is predicated upon the availability of the exemptions authorized by this Section.

A business enterprise shall be exempt, in whole or in part, from the pass-on charges of municipal utility taxes imposed under Section 9-221, only if it meets the criteria specified in clauses (1) through (3) of this Section and the municipality has adopted an ordinance authorizing the exemption under paragraph (e) of Section 8-11-2 of the Illinois Municipal Code. Upon certification of the business enterprises by the Department of Commerce and Economic Opportunity, the Department of Commerce and Economic Opportunity shall notify the Department of Revenue of such certification. The Department of Revenue shall notify the public utilities of the exemption status of business enterprises from the pass-on charges of State and municipal utility taxes. Such exemption status shall be effective within 3 months after certification of the business enterprise.

(Source: P.A. 97-818, eff. 7-16-12; 98-321, eff. 8-12-13.)

(220 ILCS 5/9-222.1A)

Sec. 9-222.1A. High impact business. Beginning on August 1, 1998 and thereafter, a business enterprise that is certified as a High Impact Business by the Department of Commerce and Economic Opportunity (formerly Department of Commerce and Community Affairs) is exempt from the tax imposed by Section 2-4 of the Electricity Excise Tax Law, if the High Impact Business is registered to self-assess that tax, and is exempt from any additional charges added to the business enterprise's utility bills as a pass-on of State utility taxes under Section 9-222 of this Act, to the extent the tax or charges are exempted by the percentage specified by the Department of Commerce and Economic Opportunity for State utility taxes, provided the business enterprise meets the following criteria:

(1) (A) it intends either (i) to make a minimum eligible investment of $12,000,000 that will be placed in service in qualified property in Illinois and is intended to create at least 500 full-time equivalent jobs at a designated location in Illinois; or (ii) to make a minimum eligible investment of $30,000,000 that will be placed in service in qualified property in Illinois and is intended to retain at least 1,500 full-time equivalent jobs at a designated location in Illinois; or

(B) it meets the criteria of subdivision (a)(3)(B), (a)(3)(C), (a)(3)(D), (a)(3)(F), (a)(3)(G), or (a)(3)(H) of Section 5.5 of the Illinois Enterprise Zone Act;

(2) it is designated as a High Impact Business by the Department of Commerce and Economic Opportunity; and

(3) it is certified by the Department of Commerce and Economic Opportunity as complying with the requirements specified in clauses (1) and (2) of this Section.

The Department of Commerce and Economic Opportunity shall determine the period during which the exemption from the Electricity Excise Tax Law and the charges imposed under Section 9-222 are in effect and shall specify the percentage of the exemption from those taxes or additional charges.

The Department of Commerce and Economic Opportunity is authorized to promulgate rules and regulations to carry out the provisions of this Section, including procedures for complying with the requirements specified in clauses (1) and (2) of this Section and procedures for applying for the exemptions authorized under this Section; to define the amounts and types of eligible investments that business enterprises must make in order to receive State utility tax exemptions or exemptions from the additional charges imposed under Section 9-222 and this Section; to approve such utility tax exemptions for business enterprises whose investments are not yet placed in service; and to require that business enterprises granted tax exemptions or exemptions from additional charges under Section 9-222 repay the exempted amount if the business enterprise fails to comply with the terms and conditions of the certification.

Upon certification of the business enterprises by the Department of Commerce and Economic Opportunity, the Department of Commerce and Economic Opportunity shall notify the Department of Revenue of the certification. The Department of Revenue shall notify the public utilities of the exemption status of business enterprises from the tax or pass-on charges of State utility taxes. The exemption status shall take effect within 3 months after certification of the business enterprise.

(Source: P.A. 102-1125, eff. 2-3-23; 103-9, eff. 6-7-23; 103-561, eff. 1-1-24; 103-605, eff. 7-1-24.)

(220 ILCS 5/9-222.2) (from Ch. 111 2/3, par. 9-222.2)

Sec. 9-222.2. Additional Charge - Recovery. The additional charge authorized by Section 9-221 or Section 9-222 shall be made (i) in the case of a tax measured by gross receipts or gross revenue, by adding to the customer's bill a uniform percentage to those amounts payable by the customer for intrastate utility service which are includible in the measure of such tax, except, however, such method is not required where practical considerations justify a utility's or telecommunications carrier's use of another just and reasonable method of recovering its entire liability for such tax, and (ii) in the case of a tax measured by the number of therms or kilowatt-hours distributed, supplied, furnished, sold, transported or transmitted, by adding to the customer's bill an amount equal to the number of therms or kilowatt-hours which are includible in the measure of such tax, multiplied by the applicable tax rate.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/9-222.3)

Sec. 9-222.3. (Repealed).

(Source: P.A. 87-750. Repealed by P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/9-223) (from Ch. 111 2/3, par. 9-223)

Sec. 9-223. Fire protection charge.

(a) The Commission may authorize any public utility engaged in the production, storage, transmission, sale, delivery or furnishing of water to impose a fire protection charge, in addition to any rate authorized by this Act, sufficient to cover a reasonable portion of the cost of providing the capacity, facilities and the water necessary to meet the fire protection needs of any municipality or public fire protection district. Such fire protection charge shall be in the form of a fixed amount per bill and shall be shown separately on the utility bill of each customer of the municipality or fire protection district. Any filing by a public utility to impose such a fire protection charge or to modify a charge shall be made pursuant to Section 9-201 of this Act. Any fire protection charge imposed shall reflect the costs associated with providing fire protection service for each municipality or fire protection district. No such charge shall be imposed directly on any municipality or fire protection district for a reasonable level of fire protection services unless provided for in a separate agreement between the municipality or the fire protection district and the utility.

(b) (Blank).

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/9-224) (from Ch. 111 2/3, par. 9-224)

Sec. 9-224. The Commission shall not consider as an expense of any public utility company, for the purpose of determining any rate or charge, any amount expended for political activity or lobbying as defined in the "Lobbyist Registration Act".

(Source: P.A. 84-617.)

(220 ILCS 5/9-225) (from Ch. 111 2/3, par. 9-225)

Sec. 9-225. (1) For the purposes of this Section:

(a) "Advertising" means the commercial use, by an electric, gas, water, or sewer utility, of any media, including newspapers, printed matter, radio and television, in order to transmit a message to a substantial number of members of the public or to such utility's consumers;

(b) "Political advertising" means any advertising for the purpose of influencing public opinion with respect to legislative, administrative or electoral matters, or with respect to any controversial issue of public importance;

(c) "Promotional advertising" means any advertising for the purpose of encouraging any person to select or use the service or additional service of a utility or the selection or installation of any appliance or equipment designed to use such utility's service; and

(d) "Goodwill or institutional advertising" means any advertising either on a local or national basis designed primarily to bring the utility's name before the general public in such a way as to improve the image of the utility or to promote controversial issues for the utility or the industry.

(2) In any general rate increase requested by any gas, electric, water, or sewer utility company under the provisions of this Act, the Commission shall not consider, for the purpose of determining any rate, charge or classification of costs, any direct or indirect expenditures for promotional, political, institutional or goodwill advertising, unless the Commission finds the advertising to be in the best interest of the Consumer or authorized as provided pursuant to subsection 3 of this Section.

(3) The following categories of advertising shall be considered allowable operating expenses for gas, electric, water, or sewer utilities:

(a) Advertising which informs consumers how they can conserve energy or water, reduce peak demand for electric or gas energy, or reduce demand for water;

(b) Advertising required by law or regulations, including advertising required under Part I of Title II of the National Energy Conservation Policy Act;

(c) Advertising regarding service interruptions, safety measures or emergency conditions;

(d) Advertising concerning employment opportunities with such utility;

(e) Advertising which promotes the use of energy efficient appliances, equipment or services;

(f) Explanations of existing or proposed rate schedules or notifications of hearings thereon;

(g) Advertising that identifies the location and operating hours of company business offices;

(h) Advertising which promotes the shifting of demand from peak to off-peak hours or which encourages the off-peak usage of the service; and

(i) "Other" categories of advertisements not includable in paragraphs (a) through (h), but which are not political, promotional, institutional or goodwill advertisements.

(Source: P.A. 95-814, eff. 8-13-08.)

(220 ILCS 5/9-226) (from Ch. 111 2/3, par. 9-226)

Sec. 9-226. In any general rate increase proceeding in which Section 9-225 of this Act applies, the following materials shall be made available to the Commission:

(a) Copies of all advertisements and scripts included in the operating expense, listing the production costs for each ad, the publication schedule and costs for each ad;

(b) Copies of all advertisements included in the operating expense purchased on a cooperative basis with manufacturers, developers or others and the company's cost for each ad; and

(c) All expenses incurred by the utility included in the operating expense for ads or scripts produced by a trade association including all monies paid to the association for advertising purposes, either in the form of dues, assessments or subscriptions.

(Source: P.A. 84-617.)

(220 ILCS 5/9-227) (from Ch. 111 2/3, par. 9-227)

Sec. 9-227. It shall be proper for the Commission to consider as an operating expense, for the purpose of determining whether a rate or other charge or classification is sufficient, donations made by a public utility for the public welfare or for charitable scientific, religious or educational purposes, provided that such donations are reasonable in amount. In determining the reasonableness of such donations, the Commission may not establish, by rule, a presumption that any particular portion of an otherwise reasonable amount may not be considered as an operating expense. The Commission shall be prohibited from disallowing by rule, as an operating expense, any portion of a reasonable donation for public welfare or charitable purposes.

(Source: P.A. 85-122.)

(220 ILCS 5/9-228)

Sec. 9-228. Limits on public utility expenses. The Commission shall not consider any of the following as an expense of any public utility company, including any allocation of those costs to the public utility from an affiliate or corporate parent, for the purpose of determining any rate or charge, any amount expended for:

(1) the pension or other post-employment benefits for an employee convicted of committing a criminal act in the course of his or her work with the utility;

(2) any severance or post-employment costs for an employee convicted of committing a criminal act in the course of his or her work with the utility; or

(3) criminal penalties, fines, fees, and costs related to criminal charges, criminal investigations, or deferred prosecution agreements.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/9-229)

Sec. 9-229. Consideration of attorney and expert compensation as an expense and intervenor compensation fund.

(a) The Commission shall specifically assess the justness and reasonableness of any amount expended by a public utility to compensate attorneys or technical experts to prepare and litigate a general rate case filing. This issue shall be expressly addressed in the Commission's final order.

(b) The State of Illinois shall create a Consumer Intervenor Compensation Fund subject to the following:

(1) Provision of compensation for Consumer Interest Representatives that intervene in Illinois Commerce Commission proceedings will increase public engagement, encourage additional transparency, expand the information available to the Commission, and improve decision-making.

(2) As used in this Section, "Consumer interest representative" means:

(A) a residential utility customer or group of residential utility customers represented by a not-for-profit group or organization registered with the Illinois Attorney General under the Solicitation for Charity Act;

(B) representatives of not-for-profit groups or organizations whose membership is limited to residential utility customers; or

(C) representatives of not-for-profit groups or organizations whose membership includes Illinois residents and that address the community, economic, environmental, or social welfare of Illinois residents, except government agencies or intervenors specifically authorized by Illinois law to participate in Commission proceedings on behalf of Illinois consumers.

(3) A consumer interest representative is eligible to receive compensation from the consumer intervenor compensation fund if its participation included lay or expert testimony or legal briefing and argument concerning the expenses, investments, rate design, rate impact, or other matters affecting the pricing, rates, costs or other charges associated with utility service, the Commission adopts a material recommendation related to a significant issue in the docket, and participation caused a significant financial hardship to the participant; however, no consumer interest representative shall be eligible to receive an award pursuant to this Section if the consumer interest representative receives any compensation, funding, or donations, directly or indirectly, from parties that have a financial interest in the outcome of the proceeding.

(4) Within 30 days after September 15, 2021 (the effective date of Public Act 102-662), each utility that files a request for an increase in rates under Article IX or Article XVI shall deposit an amount equal to one half of the rate case attorney and expert expense allowed by the Commission, but not to exceed $500,000, into the fund within 35 days of the date of the Commission's final Order in the rate case or 20 days after the denial of rehearing under Section 10-113 of this Act, whichever is later. The Consumer Intervenor Compensation Fund shall be used to provide payment to consumer interest representatives as described in this Section.

(5) An electric public utility with 3,000,000 or more retail customers shall contribute $450,000 to the Consumer Intervenor Compensation Fund within 60 days after September 15, 2021 (the effective date of Public Act 102-662). A combined electric and gas public utility serving fewer than 3,000,000 but more than 500,000 retail customers shall contribute $225,000 to the Consumer Intervenor Compensation Fund within 60 days after September 15, 2021 (the effective date of Public Act 102-662). A gas public utility with 1,500,000 or more retail customers that is not a combined electric and gas public utility shall contribute $225,000 to the Consumer Intervenor Compensation Fund within 60 days after September 15, 2021 (the effective date of Public Act 102-662). A gas public utility with fewer than 1,500,000 retail customers but more than 300,000 retail customers that is not a combined electric and gas public utility shall contribute $80,000 to the Consumer Intervenor Compensation Fund within 60 days after September 15, 2021 (the effective date of Public Act 102-662). A gas public utility with fewer than 300,000 retail customers that is not a combined electric and gas public utility shall contribute $20,000 to the Consumer Intervenor Compensation Fund within 60 days after September 15, 2021 (the effective date of Public Act 102-662). A combined electric and gas public utility serving fewer than 500,000 retail customers shall contribute $20,000 to the Consumer Intervenor Compensation Fund within 60 days after September 15, 2021 (the effective date of Public Act 102-662). A water or sewer public utility serving more than 100,000 retail customers shall contribute $80,000, and a water or sewer public utility serving fewer than 100,000 but more than 10,000 retail customers shall contribute $20,000.

(6)(A) Prior to the entry of a Final Order in a docketed case, the Commission Administrator shall provide a payment to a consumer interest representative that demonstrates through a verified application for funding that the consumer interest representative's participation or intervention without an award of fees or costs imposes a significant financial hardship based on a schedule to be developed by the Commission. The Administrator may require verification of costs incurred, including statements of hours spent, as a condition to paying the consumer interest representative prior to the entry of a Final Order in a docketed case.

(B) If the Commission adopts a material recommendation related to a significant issue in the docket and participation caused a financial hardship to the participant, then the consumer interest representative shall be allowed payment for some or all of the consumer interest representative's reasonable attorney's or advocate's fees, reasonable expert witness fees, and other reasonable costs of preparation for and participation in a hearing or proceeding. Expenses related to travel or meals shall not be compensable.

(C) The consumer interest representative shall submit an itemized request for compensation to the Consumer Intervenor Compensation Fund, including the advocate's or attorney's reasonable fee rate, the number of hours expended, reasonable expert and expert witness fees, and other reasonable costs for the preparation for and participation in the hearing and briefing within 30 days of the Commission's final order after denial or decision on rehearing, if any.

(7) Administration of the Fund.

(A) The Consumer Intervenor Compensation Fund is created as a special fund in the State treasury. All disbursements from the Consumer Intervenor Compensation Fund shall be made only upon warrants of the Comptroller drawn upon the Treasurer as custodian of the Fund upon vouchers signed by the Executive Director of the Commission or by the person or persons designated by the Director for that purpose. The Comptroller is authorized to draw the warrant upon vouchers so signed. The Treasurer shall accept all warrants so signed and shall be released from liability for all payments made on those warrants. The Consumer Intervenor Compensation Fund shall be administered by an Administrator that is a person or entity that is independent of the Commission. The administrator will be responsible for the prudent management of the Consumer Intervenor Compensation Fund and for recommendations for the award of consumer intervenor compensation from the Consumer Intervenor Compensation Fund. The Commission shall issue a request for qualifications for a third-party program administrator to administer the Consumer Intervenor Compensation Fund. The third-party administrator shall be chosen through a competitive bid process based on selection criteria and requirements developed by the Commission. The Illinois Procurement Code does not apply to the hiring or payment of the Administrator. All Administrator costs may be paid for using monies from the Consumer Intervenor Compensation Fund, but the Program Administrator shall strive to minimize costs in the implementation of the program.

(B) The computation of compensation awarded from the fund shall take into consideration the market rates paid to persons of comparable training and experience who offer similar services, but may not exceed the comparable market rate for services paid by the public utility as part of its rate case expense.

(C)(1) Recommendations on the award of compensation by the administrator shall include consideration of whether the Commission adopted a material recommendation related to a significant issue in the docket and whether participation caused a financial hardship to the participant and the payment of compensation is fair, just and reasonable.

(2) Recommendations on the award of compensation by the administrator shall be submitted to the Commission for approval. Unless the Commission initiates an investigation within 45 days after the notice to the Commission, the award of compensation shall be allowed 45 days after notice to the Commission. Such notice shall be given by filing with the Commission on the Commission's e-docket system, and keeping open for public inspection the award for compensation proposed by the Administrator. The Commission shall have power, and it is hereby given authority, either upon complaint or upon its own initiative without complaint, at once, and if it so orders, without answer or other formal pleadings, but upon reasonable notice, to enter upon a hearing concerning the propriety of the award.

(c) The Commission may adopt rules to implement this Section.

(Source: P.A. 102-662, eff. 9-15-21; 103-605, eff. 7-1-24.)

(220 ILCS 5/9-230) (from Ch. 111 2/3, par. 9-230)

Sec. 9-230. Rate of return; financial involvement with nonutility or unregulated companies. In determining a reasonable rate of return upon investment for any public utility in any proceeding to establish rates or charges, the Commission shall not include any (i) incremental risk, (ii) increased cost of capital, or (iii) after May 31, 2003, revenue or expense attributed to telephone directory operations, which is the direct or indirect result of the public utility's affiliation with unregulated or nonutility companies.

(Source: P.A. 92-22, eff. 6-30-01.)

(220 ILCS 5/9-240) (from Ch. 111 2/3, par. 9-240)

Sec. 9-240. Except as in this Act otherwise provided, no public utility shall charge, demand, collect or receive a greater or less or different compensation for any product, or commodity furnished or to be furnished, or for any service rendered or to be rendered, than the rates or other charges applicable to such product or commodity or service as specified in its schedules on file and in effect at the time, except as provided in Section 9-104, nor shall any such public utility refund or remit, directly or indirectly, in any manner or by any device, any portion of the rates or other charges so specified, nor extend to any corporation or person any form of contract or agreement or any rule or regulation or any facility or privilege except such as are regularly and uniformly extended to all corporations and persons.

No law of the State shall be construed to prohibit a public utility from furnishing its service, product or commodity to its employees, officers, directors or pensioners, or its employees, officers, directors or pensioners from receiving such service, product or commodity, free or at rates or charges less than those specified in its filed schedules.

(Source: P.A. 84-617.)

(220 ILCS 5/9-241) (from Ch. 111 2/3, par. 9-241)

Sec. 9-241. Nondiscrimination.

(a) No public utility shall, as to rates or other charges, services, facilities or in other respect, make or grant any preference or advantage to any corporation or person or subject any corporation or person to any prejudice or disadvantage. No public utility shall establish or maintain any unreasonable difference as to rates or other charges, services, facilities, or in any other respect, either as between localities or as between classes of service.

(b) An electric utility in a county with a population of 3,000,000 or more shall not establish or maintain any unreasonable difference as to rates or other charges, services, contractual terms, or facilities for access to or the use of its utility infrastructure by another person or for any other purpose. Notwithstanding any other provision of law, the Commission and its staff shall interpret this Section in accordance with Article XVI of this Act.

(c) Nothing in this Section shall be construed as limiting the authority of the Commission to permit the establishment of economic development rates as incentives to economic development either in enterprise zones as designated by the State of Illinois or in other areas of a utility's service area. Such rates should be available to existing businesses which demonstrate an increase to existing load as well as new businesses which create new load for a utility so as to create a more balanced utilization of generating capacity. The Commission shall ensure that such rates are established at a level which provides a net benefit to customers within a public utility's service area.

(d) On or before January 1, 2023, the Commission shall conduct a comprehensive study to assess whether low-income discount rates for electric and natural gas residential customers are appropriate and the potential design and implementation of any such rates. The Commission shall include its findings, together with the appropriate recommendations, in a report to be provided to the General Assembly. Upon completion of the study, the Commission shall have the authority to permit or require electric and natural gas utilities to file a tariff establishing low-income discount rates.

Such study shall assess, at a minimum, the following:

(1) customer eligibility requirements, including income-based eligibility and eligibility based on participation in or eligibility for certain public assistance programs;

(2) appropriate rate structures, including consideration of tiered discounts for different income levels;

(3) appropriate recovery mechanisms, including the consideration of volumetric charges and customer charges;

(4) appropriate verification mechanisms;

(5) measures to ensure customer confidentiality and data safeguards;

(6) outreach and consumer education procedures; and

(7) the impact that a low-income discount rate would have on the affordability of delivery service to low-income customers and customers overall.

(e) The Commission shall adopt rules requiring utility companies to produce information, in the form of a mailing, and other approved methods of distribution, to its consumers, to inform the consumers of available rebates, discounts, credits, and other cost-saving mechanisms that can help them lower their monthly utility bills, and send out such information semi-annually, unless otherwise provided by this Article.

(f) Prior to October 1, 1989, no public utility providing electrical or gas service shall consider the use of solar or other nonconventional renewable sources of energy by a customer as a basis for establishing higher rates or charges for any service or commodity sold to such customer; nor shall a public utility subject any customer utilizing such energy source or sources to any other prejudice or disadvantage on account of such use. No public utility shall without the consent of the Commission, charge or receive any greater compensation in the aggregate for a lesser commodity, product, or service than for a greater commodity, product or service of like character.

The Commission, in order to expedite the determination of rate questions, or to avoid unnecessary and unreasonable expense, or to avoid unjust or unreasonable discrimination between classes of customers, or, whenever in the judgment of the Commission public interest so requires, may, for rate making and accounting purposes, or either of them, consider one or more municipalities either with or without the adjacent or intervening rural territory as a regional unit where the same public utility serves such region under substantially similar conditions, and may within such region prescribe uniform rates for consumers or patrons of the same class.

Any public utility, with the consent and approval of the Commission, may as a basis for the determination of the charges made by it classify its service according to the amount used, the time when used, the purpose for which used, and other relevant factors.

(Source: P.A. 102-662, eff. 9-15-21; 103-679, eff. 7-19-24.)

(220 ILCS 5/9-242)

Sec. 9-242. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/9-243) (from Ch. 111 2/3, par. 9-243)

Sec. 9-243. No public utility, or any officer or agent thereof, or any person acting for or employed by it, shall directly or indirectly, by any device or means whatsoever, suffer or permit any corporation or person to obtain any service, commodity, or product at less than the rate or other charge then established and in force as shown by the schedules filed and in effect at the time. No person or corporation shall, directly or indirectly, by any device or means whatsoever, whether with or without the consent or connivance of a public utility or any of its officers, or employees, seek to obtain or obtain any service, commodity, or product at less than the rate or other charge then established and in force therefor. If prior to June 30, 1913, any real estate or other tangible property shall have been sold or transferred to any public utility or public service corporation, or, if before that date, any obligation of any public utility or public service corporation created in consideration of the transfer to it of any real estate or other tangible property, shall have been released or cancelled, upon consideration in whole or in part of an agreement by such public utility or public service corporation expressed in writing to render any service, or furnish any commodity or product in the future to the party or parties making such conveyance or transfer or owning such obligation, nothing in this Act contained shall be construed to in any way affect such agreement or to prevent the performance or enforcement thereof according to its terms, or to authorize the Commission to interfere with such performance or enforcement.

(Source: P.A. 84-617.)

(220 ILCS 5/9-244) (from Ch. 111 2/3, par. 9-244)

Sec. 9-244. Alternative rate regulation.

(a) Notwithstanding any of the ratemaking provisions of this Article IX or other Sections of this Act, or the Commission's rules that are deemed to require rate of return regulation, and except as provided in Article XVI, the Commission, upon petition by an electric or gas public utility, and after notice and hearing, may authorize for some or all of the regulated services of that utility, the implementation of one or more programs consisting of (i) alternatives to rate of return regulation, including but not limited to earnings sharing, rate moratoria, price caps or flexible rate options, or (ii) other regulatory mechanisms that reward or penalize the utility through the adjustment of rates based on utility performance. In the case of other regulatory mechanisms that reward or penalize utilities through the adjustment of rates based on utility performance, the utility's performance shall be compared to standards established in the Commission order authorizing the implementation of other regulatory mechanisms. The Commission is specifically authorized to approve in response to such petitions different forms of alternatives to rate of return regulation or other regulatory mechanisms to fit the particular characteristics and requirements of different utilities and their service territories.

(b) The Commission shall approve the program if it finds, based on the record, that:

(1) the program is likely to result in rates lower than otherwise would have been in effect under traditional rate of return regulation for the services covered by the program and that are consistent with the provisions of Section 9-241 of the Act; and

(2) the program is likely to result in other substantial and identifiable benefits that would be realized by customers served under the program and that would not be realized in the absence of the program; and

(3) the utility is in compliance with applicable Commission standards for reliability and implementation of the program is not likely to adversely affect service reliability; and

(4) implementation of the program is not likely to result in deterioration of the utility's financial condition; and

(5) implementation of the program is not likely to adversely affect the development of competitive markets; and

(6) the electric utility is in compliance with its obligation to offer delivery services pursuant to Article XVI; and

(7) the program includes annual reporting requirements and other provisions that will enable the Commission to adequately monitor its implementation of the program; and

(8) the program includes provisions for an equitable sharing of any net economic benefits between the utility and its customers to the extent the program is likely to result in such benefits.

The Commission shall issue its order approving or denying the program no later than 270 days from the date of filing of the petition. Any program approved under this Section shall continue in effect until revised, modified or terminated by order of the Commission as provided in this Section. If the Commission cannot make the above findings, it shall specifically identify in its order the reason or reasons why the proposed program does not meet the above criteria, and shall identify any modifications supported in the record, if any, that would cause the program to satisfy the above criteria. In the event the order identifies any such modifications it shall not become a final order subject to petitions for rehearing until 15 days after service of same by the Commission. The utility shall have 14 days following the date of service of the order to notify the Commission in writing whether it will accept any modifications so identified in the order or whether it has elected not to proceed with the program. If the utility notifies the Commission that it will accept such modifications, the Commission shall issue an amended order, without further hearing, within 14 days following such notification, approving the program as modified and such order shall be considered to be a final order of the Commission subject to petitions for rehearing and appellate procedures.

(c) The Commission shall open a proceeding to review any program approved under subsection (b) 2 years after the program is first implemented to determine whether the program is meeting its objectives, and may make such revisions, no later than 270 days after the proceeding is opened, as are necessary to result in the program meeting its objectives. A utility may elect to discontinue any program so revised. The Commission shall not otherwise direct a utility to revise, modify or cancel a program during its term of operation, except as found necessary, after notice and hearing, to ensure system reliability.

(d) Upon its own motion or complaint, the Commission may investigate whether the utility is implementing an approved program in accordance with the Commission order approving the program. If the Commission finds after notice and hearing, that the utility is not implementing the program in accordance with such order, the Commission shall order the utility to comply with the terms of the order. Complaints relating to the program filed under Section 9-250 of this Act, alleging that the program does not comply with that Section or the requirements of subsection (b) shall not be filed sooner than one year after the review provided for in subsection (c). The complainant shall bear the burden of proving the allegations in the complaint.

(e) The Commission shall not be authorized to allow or order an electric utility to place a program into effect, pursuant to this Section, applicable to delivery services provided by a utility, unless the utility already has in effect a delivery services tariff conforming to the requirements of Section 16-108 of this Act.

(f) The Commission may, upon subsequent petition by the utility, after notice and hearing, authorize the extension of a program that was previously approved pursuant to this Section or approve revisions or modifications of such a program to be effective, after the initially approved program has been in effect. Any such petition seeking an extension, revision, or modification of such a program must be accompanied by an evaluation of the program addressing the criteria set forth in subsection (b) hereof. The utility's petition may, but is not required to, specify a termination date for the extended, revised or modified program. The Commission may require a review of the extended, revised, or modified program at such intervals as may be ordered by the Commission, for the purpose of determining whether the program should be revised, modified, or terminated.

(Source: P.A. 89-194, eff. 1-1-96; 90-561, eff. 12-16-97.)

(220 ILCS 5/9-245)

Sec. 9-245. Rates; environmental fines and remediation. In determining the rates for a public utility engaged in providing natural gas service, the Commission may not include any expenditure for fines or remediation and related activities incurred as a result of mercury spills associated with gas pressure regulators, manometers, or any other devices containing mercury in the utility's system. Any related insurance or third party recoveries must also be excluded for ratemaking purposes.

(Source: P.A. 92-71, eff. 7-12-01.)

(220 ILCS 5/9-246)

Sec. 9-246. Rates; lead hazard cost recovery by investor-owned water utilities. In determining the rates for an investor-owned public utility engaged in providing water service, the Commission shall allow the utility to recover annually any reasonable costs incurred by the utility to comply with Section 35.5 of the Illinois Plumbing License Law.

(Source: P.A. 99-922, eff. 1-17-17.)

(220 ILCS 5/9-250) (from Ch. 111 2/3, par. 9-250)

Sec. 9-250. Whenever the Commission, after a hearing had upon its own motion or upon complaint, shall find that the rates or other charges, or classifications, or any of them, demanded, observed, charged or collected by any public utility for any service or product or commodity, or in connection therewith, or that the rules, regulations, contracts, or practices or any of them, affecting such rates or other charges, or classifications, or any of them, are unjust, unreasonable, discriminatory or preferential, or in any way in violation of any provisions of law, or that such rates or other charges or classifications are insufficient, the Commission shall determine the just, reasonable or sufficient rates or other charges, classifications, rules, regulations, contracts or practices to be thereafter observed and in force, and shall fix the same by order as hereinafter provided.

The Commission shall have power, upon a hearing, had upon its own motion or upon complaint, to investigate a single rate or other charge, classification, rule, regulation, contract or practice, or any number thereof, or the entire schedule or schedules of rates or other charges, classifications, rules, regulations, contracts and practices, or any thereof of any public utility, and to establish new rates or other charges, classifications, rules, regulations, contracts or practices or schedule or schedules, in lieu thereof.

(Source: P.A. 84-617; 84-1025.)

(220 ILCS 5/9-251) (from Ch. 111 2/3, par. 9-251)

Sec. 9-251. The Commission shall have the power to investigate all existing or proposed interstate rates or other charges, and classifications, and all rules and practices in relation thereto, of any public utility, where any act in relation thereto shall take place within this State; and when the same are, in the opinion of the Commission, excessive or discriminatory or in violation of any Act of Congress, the Commission may apply by petition or otherwise to any court of competent jurisdiction for relief.

The Commission shall also have the power, after a hearing had upon its own motion or upon complaint, to order any public utilities to establish and fix reasonable and sufficient joint rates or other charges or classifications. In case such public utilities do not agree upon the division between them of such joint rates or other charges the Commission shall, after hearing, establish such division by supplemental order.

(Source: P.A. 84-617; 84-1025.)

(220 ILCS 5/9-252) (from Ch. 111 2/3, par. 9-252)

Sec. 9-252. When complaint is made to the Commission concerning any rate or other charge of any public utility and the Commission finds, after a hearing, that the public utility has charged an excessive or unjustly discriminatory amount for its product, commodity or service, the Commission may order that the public utility make due reparation to the complainant therefor, with interest at the legal rate from the date of payment of such excessive or unjustly discriminatory amount.

If the public utility does not comply with an order of the Commission for the payment of money within the time fixed in such order, the complainant, or any person for whose benefit such order was made, may file in a circuit court of competent jurisdiction a complaint setting forth briefly the causes for which the person claims damages and the order of the Commission in the premises. Such action shall proceed in all respects like other civil actions for damages, except that on the trial of such action the order of the Commission shall be prima facie evidence of the facts therein stated. If the plaintiff shall finally prevail, he or she shall be allowed a reasonable attorney's fee to be taxed and collected as a part of the costs of the action.

All complaints for the recovery of damages shall be filed with the Commission within 2 years from the time the produce, commodity or service as to which complaint is made was furnished or performed, and a petition for the enforcement of an order of the Commission for the payment of money shall be filed in the proper court within one year from the date of the order, except that if an appeal is taken from the order of the Commission, the time from the taking of the appeal until its final adjudication shall be excluded in computing the one year allowed for filing the complaint to enforce such order.

The remedy provided in this section shall be cumulative, and in addition to any other remedy or remedies in this Act provided in case of failure of a public utility to obey a rule, regulation, order or decision of the Commission.

(Source: P.A. 88-323.)

(220 ILCS 5/9-252.1)

Sec. 9-252.1. When a customer pays a bill as submitted by a public utility and the billing is later found to be incorrect due to an error either in charging more than the published rate or in measuring the quantity or volume of service provided, the utility shall refund the overcharge with interest from the date of overpayment at the legal rate or at a rate prescribed by rule of the Commission. Refunds and interest for such overcharges may be paid by the utility without the need for a hearing and order of the Commission. Any complaint relating to an incorrect billing must be filed with the Commission no more than 2 years after the date the customer first has knowledge of the incorrect billing.

(Source: P.A. 88-323.)

(220 ILCS 5/9-253)

Sec. 9-253. Refunds.

(a) If the Commission or a court determines that a public utility has overcharged its customers and orders that a refund be made to customers of the utility, a portion of the refund shall be set aside during the refund period or for 120 days after the refund is ordered, whichever is longer, and shall be used to pay refunds to customers who were overcharged and are no longer customers of the utility. The Commission shall determine the amount to be set aside for refunds to former customers. The Commission shall periodically review the appropriateness of the amount of funds set aside for purposes of compensating former customers and make adjustments as needed.

(b) The utility ordered to make the refund shall notify the public in the form designated by the Commission. In determining the form of the notice, the Commission shall take into account the effectiveness of the format in reaching former customers as well as the administrative costs of notifying past customers.

(c) A portion of the funds set aside for refunds to former customers may be used to cover administrative costs of the refund. The Commission shall determine the reasonableness of such administrative costs and shall establish a formula for determining how much of the funds may be used for administrative costs.

(d) Only a former customer who was a customer of the utility during the period of the overcharges and who files a claim with the utility during the refund period or within 120 days after the refund is ordered, whichever is longer, and proves that he was a customer of the utility during the period of overcharges shall be entitled to a refund under this Section. A claim for a refund shall be in writing on a form provided by the utility. For purposes of this Section, "prove" means providing a copy of a past bill for utility services which shows that the claimant was a customer of record of the utility during the period of overcharges. The claimant shall not be obligated to provide a past bill if there is less than 24 months between the date of the refund and the period of the service to which the refund applies.

(e) If a former customer claims a refund and owes a past due amount to the utility, the refund amount shall be reduced by the amount the customer owes the utility and that past due amount shall be returned to the utility.

(f) Interest shall accrue on the funds set aside until all moneys have been paid out to customers.

(g) At the end of the refund period or 120 days after the refund is ordered, whichever is longer, any balance remaining after all legitimate claims for refunds have been paid shall be refunded to current customers of the utility as a credit on their bills.

(h) The Commission shall determine the formula on how amounts for refunds to former customers shall be calculated.

(i) This Section does not apply to refunds which were ordered prior to the effective date of this amendatory Act of 1994.

(j) This Section does not apply to refunds ordered in reconciliation proceedings pursuant to Section 9-220 of the Public Utilities Act.

(Source: P.A. 88-639, eff. 9-9-94.)

(220 ILCS 5/Art. X heading) ARTICLE X. PROCEEDINGS BEFORE THE COMMISSION AND THE COURTS

(220 ILCS 5/10-101) (from Ch. 111 2/3, par. 10-101)

Sec. 10-101. The Commission, or any commissioner or administrative law judge designated by the Commission, shall have power to hold investigations, inquiries and hearings concerning any matters covered by the provisions of this Act, or by any other Acts relating to public utilities subject to such rules and regulations as the Commission may establish. In the conduct of any investigation, inquiry or hearing the provisions of the Illinois Administrative Procedure Act, including but not limited to Sections 10-25 and 10-35 of that Act, shall be applicable and the Commission's rules shall be consistent therewith. Complaint cases initiated pursuant to any Section of this Act, investigative proceedings and ratemaking cases shall be considered "contested cases" as defined in Section 1-30 of the Illinois Administrative Procedure Act, any contrary provision therein notwithstanding. Any proceeding intended to lead to the establishment of policies, practices, rules or programs applicable to more than one utility may, in the Commission's discretion, be conducted pursuant to either rulemaking or contested case provisions, provided such choice is clearly indicated at the beginning of such proceeding and subsequently adhered to. No violation of this Section or the Illinois Administrative Procedure Act and no informality in any proceeding or in the manner of taking testimony before the Commission, any commissioner or administrative law judge of the Commission shall invalidate any order, decision, rule or regulation made, approved, or confirmed by the Commission in the absence of prejudice. All hearings conducted by the Commission shall be open to the public.

Each commissioner and every administrative law judge of the Commission designated by it to hold any inquiry, investigation or hearing, shall have the power to administer oaths and affirmations, certify to all official acts, issue subpoenas, compel the attendance and testimony of witnesses, and the production of papers, books, accounts and documents.

Hearings shall be held either by the Commission or by one or more commissioners or administrative law judges.

When any attorney who is not admitted to the practice of law in Illinois by unlimited or conditional admission, but who is licensed in another state, territory, or commonwealth of the United States, the District of Columbia, or a foreign country may desire to appear before the Commission, such attorney shall be allowed to appear before the Commission as provided in Supreme Court Rule 707.

All evidence presented at hearings held by the Commission or under its authority shall become a part of the records of the Commission. In all cases in which the Commission bases any action on reports of investigation or inquiries not conducted as hearings, such reports shall be made a part of the records of the Commission. All proceedings of the Commission and all documents and records in its possession shall be public records, except as in this Act otherwise provided.

To the extent consistent with this Section and the Illinois Administrative Procedure Act, the Commission may adopt reasonable and proper rules and regulations relative to the exercise of its powers, and proper rules to govern its proceedings, and regulate the mode and manner of all investigations and hearings, and alter and amend the same.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/10-101.1)

Sec. 10-101.1. Mediation; arbitration; case management.

(a) It is the intent of the General Assembly that proceedings before the Commission shall be concluded as expeditiously as is possible consistent with the right of the parties to the due process of law and protection of the public interest. It is further the intent of the General Assembly to permit and encourage voluntary mediation and voluntary binding arbitration of disputes arising under this Act.

(b) Nothing in this Act shall prevent parties to contested cases brought before the Commission from resolving those cases, or other disputes arising under this Act, in part or in their entirety, by agreement of all parties, by compromise and settlement, or by voluntary mediation; provided, however, that nothing in this Section shall limit the Commission's authority to conduct such investigations and enter such orders as it shall deem necessary to enforce the provisions of this Act or otherwise protect the public interest. Evidence of conduct or statements made by a party in furtherance of voluntary mediation or in compromise negotiations is not admissible as evidence should the matter subsequently be heard by the Commission; provided, however that evidence otherwise discoverable is not excluded or deemed inadmissible merely because it is presented in the course of voluntary mediation or compromise negotiations. No civil penalty shall be imposed upon parties that reach an agreement pursuant to the mediation procedures in this Section.

(c) The Commission shall prescribe by rule such procedures and facilities as are necessary to permit parties to resolve disputes through voluntary mediation prior to the filing of, or at any point during, the pendency of a contested matter. Parties to disputes arising under this Act are encouraged to submit disputes to the Commission for voluntary mediation, which shall not be binding upon the parties. Submission of a dispute to voluntary mediation shall not compromise the right of any party to bring action under this Act.

(d) In any contested case before the Commission, at the Commission's or administrative law judge's direction or on motion of any party, a case management conference may be held at such time in the proceeding prior to evidentiary hearing as the administrative law judge deems proper. Prior to the conference, when directed to do so, all parties shall file a case management memorandum that addresses items (1) through (9) as directed by the administrative law judge. At the conference, the following shall be considered:

(1) the identification and simplification of the issues; provided, however, that the identification of issues by a party shall not foreclose that party from raising such other meritorious issues as that party might subsequently identify;

(2) amendments to the pleadings;

(3) the possibility of obtaining admissions of fact and of documents which will avoid unnecessary proof;

(4) limitations on discovery including:

(A) the area of expertise and the number of witnesses who will likely be called; provided, however, that the identification of witnesses by a party shall not foreclose that party from producing such other witnesses as that party might subsequently identify; and

(B) schedules for responses to and completion of discovery; provided, however, that such responses shall under no circumstances be provided later than 28 days after such discovery or requests are served, unless the administrative law judge shall order or the parties agree to some other time period for response;

(5) the possibility of settlement and scheduling of a settlement conference;

(6) the advisability of alternative dispute resolution including, but not limited to, mediation or arbitration;

(7) the date on which the matter should be ready for evidentiary hearing and the likely duration of the hearing;

(8) the advisability of holding subsequent case management conferences; and

(9) any other matters that may aid in the disposition of the action.

(e) The Commission is hereby authorized, if requested by all parties to any complaint brought under this Act, to arbitrate the complaint and to enter a binding arbitration award disposing of the complaint. The Commission shall prescribe by rule procedures for arbitration.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/10-102) (from Ch. 111 2/3, par. 10-102)

Sec. 10-102. All meetings of the Commission shall be conducted pursuant to the provisions of the Open Meetings Act. Whenever the Commission holds an open meeting or, pursuant to such Act, closes any meeting, or portion of any meeting, it shall arrange for all discussions, deliberations and meetings to be transcribed verbatim by a certified court reporter. The transcripts may be provided in an electronic format only. The Commission shall review and approve all such transcripts within 30 days of the date of the meeting, but at least 10 days prior to the expiration of the time within which an application for rehearing is due in any proceeding that is the subject of the meeting. When, in the Commission's judgment, the exception of the Open Meetings Act relied upon for authorizing the closing of a meeting, as recorded pursuant to Section 2a of the Open Meetings Act, is no longer applicable, such transcripts shall be made available to the public. Any party to a Commission proceeding shall be given access to the transcript of any closed meeting pertaining to such proceeding at least 10 days prior to the expiration of the time within which his application for rehearing must be filed, upon the signing of an appropriate protective agreement. Transcripts of open Commission meetings shall be electronically posted in the relevant docket on the same day that the transcript is approved by the Commission.

(Source: P.A. 96-33, eff. 7-10-09.)

(220 ILCS 5/10-103) (from Ch. 111 2/3, par. 10-103)

Sec. 10-103. In all proceedings, investigations or hearings conducted by the Commission, except in the disposition of matters which the Commission is authorized to entertain or dispose of on an ex parte basis, any finding, decision or order made by the Commission shall be based exclusively on the record for decision in the case, which shall include only the transcript of testimony and exhibits together with all papers and requests filed in the proceeding, including, in contested cases, the documents and information described in Section 10-35 of the Illinois Administrative Procedure Act.

The provisions of Section 10-60 of the Illinois Administrative Procedure Act shall apply in full to Commission proceedings, including ratemaking cases, any provision of the Illinois Administrative Procedure Act to the contrary notwithstanding.

The provisions of Section 10-60 shall not apply, however, to communications between Commission employees who are engaged in investigatory, prosecutorial or advocacy functions and other parties to the proceeding, provided that such Commission employees are still prohibited from communicating on an ex parte basis, as designated in Section 10-60, directly or indirectly, with members of the Commission, any administrative law judge in the proceeding, or any Commission employee who is or may reasonably be expected to be involved in the decisional process of the proceeding. Any commissioner, administrative law judge, or other person who is or may reasonably be expected to be involved in the decisional process of a proceeding, who receives, or who makes or knowingly causes to be made, a communication prohibited by this Section or Section 10-60 of the Illinois Administrative Procedure Act as modified by this Section, shall place on the public record of the proceeding (1) any and all such written communications; (2) memoranda stating the substance of any and all such oral communications; and (3) any and all written responses and memoranda stating the substance of any and all oral responses to the materials described in clauses (1) and (2).

The Commission, or any commissioner or administrative law judge presiding over the proceeding, shall in the event of a violation of this Section, take whatever action is necessary to ensure that such violation does not prejudice any party or adversely affect the fairness of the proceedings, including dismissing the affected matter.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/10-104) (from Ch. 111 2/3, par. 10-104)

Sec. 10-104. All hearings before the Commission or any commissioner or administrative law judge shall be held within the county in which the subject matter of the hearing is situated, or if the subject matter of the hearing is situated in more than one county, then at a place or places designated by the Commission, or agreed upon by the parties in interest, within one or more such counties, or at the place which in the judgment of the Commission shall be most convenient to the parties to be heard.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/10-105) (from Ch. 111 2/3, par. 10-105)

Sec. 10-105. No person shall be excused from testifying or from producing any papers, books, accounts or documents in any investigation or inquiry or upon any hearing ordered by the Commission, when ordered to do so by the Commission or any commissioner or administrative law judge, upon the ground that the testimony or evidence, documentary or otherwise, may tend to incriminate him or subject him to a penalty or forfeiture. But no person shall be prosecuted or subjected to any penalty or forfeiture for or on account of any transaction, matter or thing concerning which he may testify or produce evidence, documentary or otherwise, before the Commission or a commissioner or administrative law judge: Provided, that such immunity shall extend only to a natural person, who in obedience to a subpoena, gives testimony under oath or produces evidence, documentary or otherwise under oath. No person so testifying shall be exempt from prosecution and punishment for perjury committed in so testifying. The Commission or a commissioner or administrative law judge may, on the motion of a party or on its own motion, strike, in whole or in part, the testimony of a person who is not reasonably prepared to respond to questions under cross-examination intending to elicit information directly related to matters raised by that person in his testimony.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/10-106) (from Ch. 111 2/3, par. 10-106)

Sec. 10-106. All subpoenas issued under the terms of this Act may be served by any person of full age. The fees of witnesses for attendance and travel shall be the same as fees of witnesses before the circuit courts of this State, such fees to be paid when the witness is excused from further attendance, when the witness is subpoenaed at the instance of the Commission, or any commissioner or administrative law judge; and the disbursements made in the payment of such fees shall be audited and paid in the same manner as are other expenses of the Commission. Whenever a subpoena is issued at the instance of a complainant, respondent, or other party to any proceeding before the Commission, the Commission may require that the cost of service thereof and the fee of the witness shall be borne by the party at whose instance the witness is summoned, and the Commission shall have power, in its discretion, to require a deposit to cover the cost of such service and witness fees and the payment of the legal witness fee and mileage to the witness when served with subpoena. A subpoena issued as aforesaid shall be served in the same manner as a subpoena issued out of a court.

Any person who shall be served with a subpoena to appear and testify, or to produce books, papers, accounts or documents, issued by the Commission or by any commissioner or administrative law judge, in the course of an inquiry, investigation or hearing conducted under any of the provisions of this Act, and who refuse or neglect to appear, or to testify, or to produce books, papers, accounts and documents relevant to said inquiry, investigation or hearing as commanded in such subpoena, shall be guilty of a Class A misdemeanor.

Any circuit court of this State, upon application of the Commission, or a commissioner or administrative law judge, may, in its discretion, compel the attendance of witnesses, the production of books, papers, accounts and documents, and the giving of testimony before the Commission, or before any such commissioner or administrative law judge, by an attachment for contempt or otherwise, in the same manner as production of evidence may be compelled before the court.

The Commission or a commissioner or administrative law judge or any party may in any investigation or hearing before the Commission, cause the deposition of witnesses residing within or without the State to be taken in the manner prescribed by law for like depositions in civil actions in the courts of this State and to that end may compel the attendance of witnesses and the production of papers, books, accounts and documents.

The Commission may require, by order served on any public utility in the manner provided herein for the service of orders, the production within this State at such time and place as it may designate, of any books, accounts, papers or documents kept by any public utility operating within this State in any office or place without this State, or, at its option, verified copies in lieu thereof, so that an examination thereof may be made by the Commission or under its direction.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/10-107) (from Ch. 111 2/3, par. 10-107)

Sec. 10-107. The Commission, each commissioner and each employee of the Commission properly authorized thereby shall have the right, at any and all times to inspect the papers, books, accounts and documents, plant, equipment or other property of any public utility, and the Commission, each commissioner and any administrative law judge of the Commission authorized to administer oaths shall have the power to examine under oath any officer, agent or employee of such public utility in relation to any matter within the jurisdiction of the Commission. A person other than a commissioner or administrative law judge demanding such inspection shall produce under the seal of the Commission his authority to make such inspection. A written record of the testimony or statement so given under oath shall be made and filed with the Commission. Information so obtained shall not be admitted in evidence or used in any proceeding except in proceedings provided for in this Act.

Any party to a proceeding before the Commission shall have the right to inspect the records of all hearings, investigations or inquiries conducted by or under the authority of the Commission, which may relate to the issues involved in such proceeding; and to submit suggestions as to other matters to be investigated or as to questions to be propounded. If the Commission is satisfied that such suggested investigation should be made or such suggested questions answered, and that the information desired is within the power of either party to furnish, it shall enter an order requiring the investigation to be made or the questions to be answered, and upon failure or refusal to comply with such order, the Commission shall either refuse to grant the relief prayed for by the party refusing to comply, or may grant the relief prayed for by the opposing party against the party refusing to comply.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/10-108) (from Ch. 111 2/3, par. 10-108)

Sec. 10-108. Complaints; notice; parties. Complaint may be made by the Commission, of its own motion or by any person or corporation, chamber of commerce, board of trade, or any industrial, commercial, mercantile, agricultural or manufacturing society, or any body politic or municipal corporation by petition or complaint in writing, setting forth any act or things done or omitted to be done in violation, or claimed to be in violation, of any provision of this Act, or of any order or rule of the Commission. In the discretion of the Commission, matters presented by one complaint may be ordered separated, and matters upon which complaint may be founded may be joined. No objection shall be sustained to a separation merely because the matters separated are under the ownership, control or management of the same persons or corporation. No complaint shall be dismissed because of the absence of direct damage to the complainant.

Upon the filing of a complaint the Commission shall cause a copy thereof to be served upon the person or corporation complained of which shall be accompanied by a notice requiring that the complaint be satisfied and answered within a reasonable time to be specified by the Commission or within the discretion of the Commission, by a notice fixing a time when and place where a hearing will be had upon such complaint. Notice of the time and place shall also be given to the complainant and to such other persons as the Commission shall deem necessary. The Commission shall have authority to hear and investigate any complaint notwithstanding the fact that the person or corporation complained of may have satisfied the complaint.

The time fixed for such hearing shall not be less than ten days after the date of the service of such notice and complaint except as herein provided. Service in all hearings, investigations, and proceedings before the Commission may be made upon any person upon whom a summons may be served in accordance with the provisions of the Civil Practice Law and all existing and future amendments thereto and modifications thereof and the Supreme Court Rules now or hereafter adopted in relation to that Law, and may be made personally, by electronic means, or by mailing same in the United States mail in a sealed envelope with postage prepaid. The provisions of this section as to notice shall apply to all hearings held by the Commission or under its authority.

Any public utility shall have a right to complain on any of the grounds upon which complaints are allowed to be filed by other parties, and the same procedure shall be adopted and followed as in other cases.

All cities shall have power to appear as complainants or to make application before the Illinois Commerce Commission for an inquiry, investigation or hearing relating to the rates or other charges or services of public utilities within such city; and in case of any inquiry, investigation or hearing by or before the Illinois Commerce Commission on any matter relating to the rates or other charges or services within any city, the city shall receive written notice not less than ten days before such inquiry, investigation or hearing, and shall be entitled to appear and present evidence relating to the subject matter of such inquiry, investigation or hearing. Such notice shall be served upon the city clerk.

Whenever there shall be filed a complaint under Article IX of this Act regarding the rates, charges, classifications or services of a public utility, the Commission shall make and render findings concerning the subject matter and facts complained of and enter its order based thereon not later than one year after the filing of such complaint unless all parties to the complaint proceeding under Article IX agree to a period of greater than one year, provided that any agreement to extend the one year period must be in writing and must be for a specified period of time not exceeding 60 days. The parties may enter into more than one agreement to extend time.

In the event that the Commission fails to enter its order within one year after the filing of the complaint or upon the expiration of the last agreement to extend time, any party may file a complaint in the circuit court for an emergency order of mandamus to direct and compel the Commission to enter its order within 60 days of the expiration of the one year period or within 60 days of the expiration of the last agreement to extend time, and the court shall set a schedule to enable the Commission to complete the case and enter an order within the time frame specified herein. Summons upon the complaint shall be returnable within 5 days. The complaint for an order of mandamus shall be brought in the circuit in which the subject matter of the complaint is situated or, if the subject matter of the hearing is situated in more than one circuit, then in any one of those circuits.

(Source: P.A. 91-341, eff. 7-29-99.)

(220 ILCS 5/10-109) (from Ch. 111 2/3, par. 10-109)

Sec. 10-109. The Commission shall have power to receive complaints regarding loss or damage occasioned by a public utility, and to make inquiry as to the methods of adjusting such claims. All claims against any public utility for loss of, or damage to property, or for any other loss or damage, in connection with a public utility service, not covered by the preceding paragraphs of this section, if not acted upon within 90 days from the date of the filing of the claim with the public utility, may be investigated by the Commission, in its discretion, and the results of such investigation shall be embodied in a special report which shall be open to public inspection.

(Source: P.A. 84-617.)

(220 ILCS 5/10-110) (from Ch. 111 2/3, par. 10-110)

Sec. 10-110. At the time fixed for any hearing upon a complaint, the complainant and the person or corporation complained of, and such persons or corporations as the Commission may allow to intervene, shall be entitled to be heard and to introduce evidence. The Commission shall issue process to enforce the attendance of all necessary witnesses. At the conclusion of such hearing the Commission shall make and render findings concerning the subject matter and facts inquired into and enter its order based thereon. A copy of such order, certified under the seal of the Commission, shall be served upon the person or corporation complained of, or his or its attorney, which order shall, of its own force, take effect and become operative twenty days after the service thereof, except as otherwise provided, and shall continue in force either for a period which may be designated therein or until changed or abrogated by the Commission. Where an order cannot, in the judgment of the Commission, be complied with within twenty days, the Commission may prescribe such additional time as in its judgment is reasonably necessary to comply with the order, and may, on application and for good cause shown, extend the time for compliance fixed in its order. A full and complete record shall be preserved of all proceedings had before the Commission, or any member thereof, or any administrative law judge, on any formal hearing had, and all testimony shall be taken down by a stenographer appointed by the Commission, and the parties shall be entitled to be heard in person or by attorney.

In any proceeding involving a public utility in which the lawfulness of any of its rates or other charges shall be called in question by any person or corporation furnishing a commodity or service in competition with said public utility at prices or charges not subject to regulation, the Commission may investigate the competitive prices or other charges demanded or received by such person or corporation for such commodity or service, including the rates or other charges applicable to the transportation thereof. The Commission may, on its own motion or that of any party to such proceeding, issue subpoenas to secure the appearance of witnesses or the production of books, papers, accounts and documents necessary to ascertain the prices, rates or other charges for such commodity or service or for the transportation thereof, and shall dismiss from such proceeding any party failing to comply with a subpoena so issued.

In case of an appeal from any order or decision of the Commission, under the terms of Sections 10-201 and 10-202 of this Act, a transcript of such testimony, together with all exhibits or copies thereof introduced and all information secured by the Commission on its own initiative and considered by it in rendering its order or decision (and required by this Act to be made a part of its records) and of the pleadings, records and proceedings in the case, including transcripts of Commission meetings prepared in accordance with Section 10-102 of this Act, shall constitute the record of the Commission: Provided, that on appeal from an order or decision of the Commission, the person or corporation taking the appeal and the Commission may stipulate that a certain question or certain questions alone and a specified portion only of the evidence shall be certified to the court for its judgment, whereupon such stipulation and the question or questions and the evidence therein specified shall constitute the record on appeal.

Copies of all official documents and orders filed or deposited according to law in the office of the Commission, certified by the Chairman of the Commission or his or her designee to be true copies of the originals, under the official seal of the Commission, shall be evidence in like manner as the originals.

In any matter concerning which the Commission is authorized to hold a hearing, upon complaint or application or upon its own motion, notice shall be given to the public utility and to such other interested persons as the Commission shall deem necessary in the manner provided in Section 10-108, and the hearing shall be conducted in like manner as if complaint had been made to or by the Commission. But nothing in this Act shall be taken to limit or restrict the power of the Commission, summarily, of its own motion, with or without notice, to conduct any investigations or inquiries authorized by this Act, in such manner and by such means as it may deem proper, and to take such action as it may deem necessary in connection therewith. With respect to any rules, regulations, decisions or orders which the Commission is authorized to issue without a hearing, and so issues, any public utility or other person or corporation affected thereby and deeming such rules, regulations, decisions or orders, or any of them, improper, unreasonable or contrary to law, may apply for a hearing thereon, setting forth specifically in such application every ground of objection which the applicant desires to urge against such rule, regulation, decision or order. The Commission may, in its discretion, grant or deny the application, and a hearing, if had, shall be subject to the provisions of this and the preceding Sections.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/10-111) (from Ch. 111 2/3, par. 10-111)

Sec. 10-111. In any hearing, proceeding, investigation, or rulemaking conducted by the Commission, the Commission, commissioner, or administrative law judge presiding, shall, after the close of evidentiary hearings, prepare a recommended or tentative decision, finding, or order, including a statement of findings and conclusions and the reasons or basis therefore, on all the material issues of fact, law, or discretion presented on the record. Such recommended or tentative decision, finding, or order shall be served on all parties who shall be entitled to a reasonable opportunity to respond thereto, either in briefs or comments otherwise to be filed or separately. The recommended or tentative decision, finding, or order and any responses thereto shall be included in the record for decision. This Section shall not apply to any hearing, proceeding, or investigation conducted under Section 13-515.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/10-112) (from Ch. 111 2/3, par. 10-112)

Sec. 10-112. Service of Commission orders. Every order of the Commission shall be served upon every person or corporation to be affected thereby by personal delivery of a copy thereof, by mailing in the United States mail a copy thereof in a sealed package with postage prepaid, or by electronic means to the person to be affected thereby or in the case of a corporation, to any officer or agent thereof upon whom a summons of a circuit court may be served in a civil action. Where such persons or corporations, or both, exceed 3 in number, service as herein provided may be upon the attorneys or representatives of record, if there be any; and in any event, mailing in the United States mail as herein provided, shall constitute service, without additional proof of a receipt of such copy or copies of such order. Within a time specified in the order of the Commission every person and corporation upon whom it is served must, if so required in the order, notify the Commission in like manner whether the terms of the order are accepted and will be obeyed.

(Source: P.A. 91-341, eff. 7-29-99.)

(220 ILCS 5/10-113) (from Ch. 111 2/3, par. 10-113)

Sec. 10-113. Rescission or hearing of order.

(a) Anything in this Act to the contrary notwithstanding, the Commission may at any time, upon notice to the public utility affected, and after opportunity to be heard as provided in the case of complaints, rescind, alter or amend any rule, regulation, order or decision made by it. Any order rescinding, altering or amending a prior rule, regulation, order or decision shall, when served upon the public utility affected, have the same effect as is herein provided for original rules, regulations, orders or decisions. Within 30 days after the service of any rule or regulation, order or decision of the Commission any party to the action or proceeding may apply for a rehearing in respect to any matter determined in said action or proceeding and specified in the application for rehearing. The Commission shall receive and consider such application and shall grant or deny such application in whole or in part within 20 days from the date of the receipt thereof by the Commission. In case the application for rehearing is granted in whole or in part the Commission shall proceed as promptly as possible to consider such rehearing as allowed. No appeal shall be allowed from any rule, regulation, order or decision of the Commission unless and until an application for a rehearing thereof shall first have been filed with and finally disposed of by the Commission: provided, however, that in case the Commission shall fail to grant or deny an application for a rehearing in whole or in part within 20 days from the date of the receipt thereof, or shall fail to enter a final order upon rehearing within 150 days after such rehearing is granted, the application for rehearing shall be deemed to have been denied and finally disposed of, and an order to that effect shall be deemed to have been served, for the purpose of an appeal from the rule, regulation, order or decision covered by such application. No person or corporation in any appeal shall urge or rely upon any grounds not set forth in such application for a rehearing before the Commission. An application for rehearing shall not excuse any corporation or person from complying with and obeying any rule, regulation, order or decision or any requirement of any rule, regulation, order or decision of the Commission theretofore made, or operate in any manner to stay or postpone the enforcement thereof, except in such cases and upon such terms as the Commission may by order direct. If, after such rehearing and consideration of all the facts, including those arising since the making of the rule, regulation, order or decision, the Commission shall be of the opinion that the original rule, regulation, order or decision or any part thereof is in any respect unjust or unwarranted, or should be changed, the Commission may rescind, alter or amend the same. A rule, regulation, order or decision made after such rehearing, rescinding, altering or amending the original rule, regulation, order or decision shall have the same force and effect as an original rule, regulation, order or decision, but shall not affect any right or the enforcement of any right arising from or by virtue of the original rule, regulation, order or decision unless so ordered by the Commission. Only one rehearing shall be granted by the Commission; but this shall not be construed to prevent any party from filing a petition setting up a new and different state of facts after 2 years, and invoking the action of the Commission thereon.

(b) Notwithstanding any contrary or inconsistent provision in the Illinois Administrative Procedure Act, the Commission may, in accordance with this Section, make a change in a rule or regulation adopted or modified pursuant to Section 5-40 of the Illinois Administrative Procedure Act, upon consideration of an application for rehearing of the Commission's order directing that the rule or regulation be filed with the Secretary of State and published in the Illinois Register pursuant to subsection (d) of Section 5-40. The Commission shall provide the parties to the original hearing in which the rule was adopted or modified no less than 7 days notice to provide responses to the change the Commission proposes to make. Any such change shall be based upon evidence submitted in the record in the original hearing or in the rehearing. If the Commission makes such a substantive change in the rule or regulation pursuant to this subsection, it shall provide notice of the amendment to the rule or regulation to the Joint Committee on Administrative Rules in accordance with subsection (c) of Section 5-40, and shall thereafter comply with the requirements of subsection (d) of Section 5-40 with respect to the rule or regulation as amended. The running of the time period specified in subsection (e) of Section 5-40 of the Illinois Administrative Procedure Act for completing a rulemaking proceeding shall be tolled for the period of time necessary for the Commission to receive and consider an application for rehearing and to conduct any proceedings on rehearing, provided, that such tolling shall not serve to extend any of the time periods provided for in subsection (a) of this Section.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/10-201) (from Ch. 111 2/3, par. 10-201)

Sec. 10-201. (a) Jurisdiction. Within 35 days from the date that a copy of the order or decision sought to be reviewed was served upon the party affected by any order or decision of the Commission refusing an application for a rehearing of any rule, regulation, order or decision of the Commission, including any order granting or denying interim rate relief, or within 35 days from the date that a copy of the order or decision sought to be reviewed was served upon the party affected by any final order or decision of the Commission upon and after a rehearing of any rule, regulation, order or decision of the Commission, including any order granting or denying interim rate relief, any person or corporation affected by such rule, regulation, order or decision, may appeal to the appellate court of the judicial district in which the subject matter of the hearing is situated, or if the subject matter of the hearing is situated in more than one district, then of any one of such districts, for the purpose of having the reasonableness or lawfulness of the rule, regulation, order or decision inquired into and determined.

The court first acquiring jurisdiction of any appeal from any rule, regulation, order or decision shall have and retain jurisdiction of such appeal and of all further appeals from the same rule, regulation, order or decision until such appeal is disposed of in such appellate court.

(b) Pleadings and record. No proceeding to contest any rule, regulation, decision or order which the Commission is authorized to issue without a hearing and has so issued shall be brought in any court unless application shall have been first made to the Commission for a hearing thereon and until after such application has been acted upon by the Commission, nor shall any person or corporation in any court urge or rely upon any grounds not set forth in such application for a hearing before the Commission, but the Commission shall decide the questions presented by the application with all possible expedition consistent with the duties of the Commission. The party taking such an appeal shall file with the Commission written notice of the appeal. The Commission, upon the filing of such notice of appeal, shall, within 5 days thereafter, file with the clerk of the appellate court to which such appeal is taken a certified copy of the order appealed. The Commission shall prepare a copy of the transcript of the evidence, including exhibits and transcripts of Commission meetings prepared in accordance with Section 10-102 of this Act, or any portion of the record designated in a stipulation that only certain questions are involved on appeal, which stipulation is to be included in the record provided for in Section 10-110. The Commission shall certify the record and file the same with the clerk of the appellate court to which such appeal is taken within 35 days of the filing of the notice of appeal. The party serving such notice of appeal shall, within 5 days after the service of such notice upon the Commission, file a copy of the notice, with proof of service, with the clerk of the court to which such appeal is taken, and thereupon the appellate court shall have jurisdiction over the appeal. The appeal shall be heard according to the rules governing other civil cases, so far as the same are applicable.

(c) No appellate court shall permit a party affected by any rule, regulation, order or decision of the Commission to intervene or become a party plaintiff or appellant in such court who has not taken an appeal from such rule, regulation, order or decision in the manner as herein provided.

(d) No new or additional evidence may be introduced in any proceeding upon appeal from a rule, regulation, order or decision of the Commission, issued or confirmed after a hearing, but the appeal shall be heard on the record of the Commission as certified by it. The findings and conclusions of the Commission on questions of fact shall be held prima facie to be true and as found by the Commission; rules, regulations, orders or decisions of the Commission shall be held to be prima facie reasonable, and the burden of proof upon all issues raised by the appeal shall be upon the person or corporation appealing from such rules, regulations, orders or decisions.

(e) Powers and duties of reviewing court:

(i) An appellate court to which any such appeal is taken shall have the power, and it shall be its duty, to hear and determine such appeal with all convenient speed. Any proceeding in any court in this State directly affecting a rule, regulation, order or decision of the Commission, or to which the Commission is a party, shall have priority in hearing and determination over all other civil proceedings pending in such court, excepting election contests.

(ii) If it appears that the Commission failed to receive evidence properly proffered, on a hearing or a rehearing, or an application therefor, the court shall remand the case, in whole or in part, to the Commission with instructions to receive the testimony so proffered and rejected, and to enter a new order based upon the evidence theretofore taken, and such new evidence as it is directed to receive, unless it shall appear that such new evidence would not be controlling, in which case the court shall so find in its order. If the court remands only part of the Commission's rule, regulation, order or decision, it shall determine without delay the lawfulness and reasonableness of any independent portions of the rule, regulation, order or decision subject to appeal.

(iii) If the court determines that the Commission's rule, regulation, order or decision does not contain findings or analysis sufficient to allow an informed judicial review thereof, the court shall remand the rule, regulation, order or decision, in whole or in part, with instructions to the Commission to make the necessary findings or analysis.

(iv) The court shall reverse a Commission rule, regulation, order or decision, in whole or in part, if it finds that:

A. The findings of the Commission are not supported by substantial evidence based on the entire record of evidence presented to or before the Commission for and against such rule, regulation, order or decision; or

B. The rule, regulation, order or decision is without the jurisdiction of the Commission; or

C. The rule, regulation, order or decision is in violation of the State or federal constitution or laws; or

D. The proceedings or manner by which the Commission considered and decided its rule, regulation, order or decision were in violation of the State or federal constitution or laws, to the prejudice of the appellant.

(v) The court may affirm or reverse the rule, regulation, order or decision of the Commission in whole or in part, or remand the decision in whole or in part where a hearing has been held before the Commission, and state the questions requiring further hearings or proceedings and give such other instructions as may be proper.

(vi) When the court remands a rule, regulation, order or decision of the Commission, in whole or in part, the Commission shall enter its final order with respect to the remanded rule, regulation, order or decision no later than 6 months after the date of issuance of the court's mandate. The Commission shall enter its final order, with respect to any remanded matter pending before it on the effective date of this amendatory Act of 1988, no later than 6 months after the effective date of this amendatory Act of 1988. However, when the court mandates, or grants an extension of time which the court determines to be necessary for, the taking of additional evidence, the Commission shall enter an interim order within 6 months after the issuance of the mandate (or within 6 months after the effective date of this amendatory Act of 1988 in the case of a remanded matter pending before it on the effective date of this amendatory Act of 1988), and the Commission shall enter its final order within 5 months after the date the interim order was entered.

(f) When no appeal is taken from a rule, regulation, order or decision of the Commission, as herein provided, parties affected by such rule, regulation, order or decision, shall be deemed to have waived the right to have the merits of the controversy reviewed by a court and there shall be no trial of the merits of any controversy in which such rule, regulation, order or decision was made, by any court to which application may be made for the enforcement of the same, or in any other judicial proceedings.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/10-202) (from Ch. 111 2/3, par. 10-202)

Sec. 10-202. Appeals from all final orders and judgments entered by the appellate court, in review of rules, regulations, orders or decisions of the Commission, may be taken to the Illinois Supreme Court as in other civil cases.

(Source: P.A. 84-617.)

(220 ILCS 5/10-203) (from Ch. 111 2/3, par. 10-203)

Sec. 10-203. In all appeals from the orders and decisions of the Commission, it shall be the duty of the Attorney General to represent the Commission and defend its orders and decisions.

(Source: P.A. 84-617.)

(220 ILCS 5/10-204) (from Ch. 111 2/3, par. 10-204)

Sec. 10-204. (a) The pendency of an appeal shall not of itself stay or suspend the operation of the rule, regulation, order or decision of the Commission, but during the pendency of the appeal the reviewing court may in its discretion stay or suspend, in whole or in part, the operation of the Commission's rule, regulation, order or decision. Any stocks or stock certificates, bonds, notes, or other evidence of indebtedness issued pursuant to and in accordance with an order of the Commission shall be valid and binding in accordance with their terms notwithstanding such order of the Commission is later vacated, modified, or otherwise held to be wholly or partly invalid unless operation of such order of the Commission has been stayed or suspended by the reviewing court prior to such issuance.

(b) No order so staying or suspending a rule, regulation, order or decision of the Commission shall be made by the court otherwise than upon 3 days' notice to the Commission and after a hearing, and if the rule, regulation, order or decision of the Commission is suspended, the order suspending the same shall contain a specific finding based upon evidence submitted to the court, and identified by reference thereto, that great or irreparable damage would otherwise result to the petitioner, and specifying the nature of the damage.

(c) In case the rule, regulation, order or decision of the Commission is stayed or suspended, the order of the court shall not become effective until a suspending bond shall first have been executed and filed with, and approved by the Commission (or approved, on review, by the court) payable to the people of the State of Illinois, and sufficient in amount and security to insure the prompt payment, by the party petitioning for the review, of all damages caused by the delay in the enforcement of the rule, regulation, order or decision of the Commission, and of all moneys which any person or corporation may be compelled to pay, pending the review proceedings, for transportation, transmission, product, commodity or service in excess of the charges fixed by the rule, regulation, order or decision of the Commission, in case said rule, regulation, order or decision is sustained. However, no bond shall be required in the case of any stay or suspension granted on application of the State or people of the State, represented by the Attorney General or Public Counsel, or of any city or other governmental body. The court in case it stays or suspends the rule, regulation, order or decision of the Commission in any manner affecting rates or other charges or classifications, may in its discretion, also by order direct the public utility affected to pay into court, from time to time thereto to be impounded until the final decision of the case or into some bank or trust company paying interest on deposits, under such conditions as the court may prescribe, all sums of money which it may collect from any corporation or person in excess of the sum such corporation or person would have been compelled to pay if the rule, regulation, order or decision of the Commission had not been stayed or suspended.

(d) When any rate or other charge has been in force for any length of time exceeding one year, and that rate or other charge is advanced by the public utility and the order of the Commission reinstates that prior rate or other charge, in whole or in part, no suspending order shall be allowed in any case from the reinstating order pending the final determination of the case in the reviewing court, pending the final determination by such reviewing court.

(Source: P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/Art. XI heading) ARTICLE XI. OFFICE OF PUBLIC COUNSEL (Repealed by P.A. 91-798, eff. 7-9-00)

(220 ILCS 5/11-101) (from Ch. 111 2/3, par. 11-101)

Sec. 11-101. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/11-201) (from Ch. 111 2/3, par. 11-201)

Sec. 11-201. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/11-202) (from Ch. 111 2/3, par. 11-202)

Sec. 11-202. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/11-203) (from Ch. 111 2/3, par. 11-203)

Sec. 11-203. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/11-204) (from Ch. 111 2/3, par. 11-204)

Sec. 11-204. (Repealed).

(Source: P.A. 84-1118. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/11-205) (from Ch. 111 2/3, par. 11-205)

Sec. 11-205. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/11-206) (from Ch. 111 2/3, par. 11-206)

Sec. 11-206. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/11-207) (from Ch. 111 2/3, par. 11-207)

Sec. 11-207. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/11-208) (from Ch. 111 2/3, par. 11-208)

Sec. 11-208. (Repealed).

(Source: P.A. 84-617. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/11-301) (from Ch. 111 2/3, par. 11-301)

Sec. 11-301. (Repealed).

(Source: P.A. 84-1025. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/11-302) (from Ch. 111 2/3, par. 11-302)

Sec. 11-302. (Repealed).

(Source: P.A. 90-372, eff. 7-1-98. Repealed by P.A. 91-798, eff. 7-9-00.)

(220 ILCS 5/12-103)

Sec. 12-103. (Renumbered).

(Source: P.A. 95-481, eff. 8-28-07; renumbered by P.A. 95-876, eff. 8-21-08.)

(220 ILCS 5/Art. XIII heading) ARTICLE XIII. TELECOMMUNICATIONS(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-100) (from Ch. 111 2/3, par. 13-100)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-100. This Article shall be known and may be cited as the Universal Telephone Service Protection Law of 1985.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-101) (from Ch. 111 2/3, par. 13-101)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-101. Application of Act to telecommunications rates and services. The Sections of this Act pertaining to public utilities, public utility rates and services, and the regulation thereof, are fully and equally applicable to noncompetitive telecommunications rates and services, and the regulation thereof, except to the extent modified or supplemented by the specific provisions of this Article or where the context clearly renders such provisions inapplicable. Articles I through IV, Sections 5-101, 5-106, 5-108, 5-110, 5-201, 5-202.1, 5-203, 8-301, 8-305, 8-501, 8-502, 8-503, 8-505, 8-509, 8-509.5, 8-510, 9-221, 9-222, 9-222.1, 9-222.2, 9-241, 9-250, and 9-252.1, and Article X of this Act are fully and equally applicable to the noncompetitive and competitive services of an Electing Provider and to competitive telecommunications rates and services, and the regulation thereof except that Section 5-109 shall apply to the services of an Electing Provider and to competitive telecommunications rates and services only to the extent that the Commission requires annual reports authorized by Section 5-109, provided the telecommunications provider may use generally accepted accounting practices or accounting systems it uses for financial reporting purposes in the annual report, and except that Sections 8-505 and 9-250 shall not apply to competitive retail telecommunications services and Sections 8-501 and 9-241 shall not apply to competitive services; in addition, as to competitive telecommunications rates and services, and the regulation thereof, and with the exception of competitive retail telecommunications service rates and services, all rules and regulations made by a telecommunications carrier affecting or pertaining to its charges or service shall be just and reasonable. As of the effective date of this amendatory Act of the 92nd General Assembly, Sections 4-202, 4-203, and 5-202 of this Act shall cease to apply to telecommunications rates and services.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-102) (from Ch. 111 2/3, par. 13-102)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-102. Findings. With respect to telecommunications services, as herein defined, the General Assembly finds that:

(a) universally available and widely affordable telecommunications services are essential to the health, welfare and prosperity of all Illinois citizens;

(b) federal regulatory and judicial rulings in the 1980s caused a restructuring of the telecommunications industry and opened some aspects of the industry to competitive entry, thereby necessitating revision of State telecommunications regulatory policies and practices;

(c) revisions in telecommunications regulatory policies and practices in Illinois beginning in the mid-1980s brought the benefits of competition to consumers in many telecommunications markets, but not in local exchange telecommunications service markets;

(d) the federal Telecommunications Act of 1996 established the goal of opening all telecommunications service markets to competition and accords to the states the responsibility to establish and enforce policies necessary to attain that goal;

(e) it is in the immediate interest of the People of the State of Illinois for the State to exercise its rights within the new framework of federal telecommunications policy to ensure that the economic benefits of competition in all telecommunications service markets are realized as effectively as possible;

(f) the competitive offering of all telecommunications services will increase innovation and efficiency in the provision of telecommunications services and may lead to reduced prices for consumers, increased investment in communications infrastructure, the creation of new jobs, and the attraction of new businesses to Illinois;

(g) protection of the public interest requires changes in the regulation of telecommunications carriers and services to ensure, to the maximum feasible extent, the reasonable and timely development of effective competition in all telecommunications service markets;

(h) Illinois residents rely on today's modern wired and wireless Internet Protocol (IP) networks and services to improve their lives by connecting them to school and college degrees, work and job opportunities, family and friends, information, and entertainment, as well as emergency responders and public safety officials; Illinois businesses rely on these modern IP networks and services to compete in a global marketplace by expanding their customer base, managing inventory and operations more efficiently, and offering customers specialized and personalized products and services; without question, Illinois residents and our State's economy rely profoundly on the modern wired and wireless IP networks and services in our State;

(i) the transition from 20th century traditional circuit switched and other legacy telephone services to modern 21st century next generation Internet Protocol (IP) services is taking place at an extraordinary pace as Illinois consumers are upgrading to home communications service using IP technology, including high speed Internet, Voice over Internet Protocol, and wireless service;

(j) this rapid transition to IP-based communications has dramatically transformed the way people communicate and has provided significant benefits to consumers in the form of innovative functionalities resulting from the seamless convergence of voice, video, and text, benefits realized by the General Assembly when it chose to transition its own telecommunications system to an all IP communications network in 2016;

(k) the benefits of the transition to IP-based networks and services were also recognized by the General Assembly in 2015 through the enactment of legislation requiring that every 9-1-1 emergency system in Illinois provide Next Generation 9-1-1 service by July 1, 2020, and requiring that the Next Generation 9-1-1 network must be an IP-based platform; and

(l) completing the transition to all IP-based networks and technologies is in the public interest because it will promote continued innovation, consumer benefits, increased efficiencies, and increased investment in IP-based networks and services.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-103) (from Ch. 111 2/3, par. 13-103)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-103. Policy. Consistent with its findings, the General Assembly declares that it is the policy of the State of Illinois that:

(a) telecommunications services should be available to all Illinois citizens at just, reasonable, and affordable rates and that such services should be provided as widely and economically as possible in sufficient variety, quality, quantity and reliability to satisfy the public interest;

(b) consistent with the protection of consumers of telecommunications services and the furtherance of other public interest goals, competition in all telecommunications service markets should be pursued as a substitute for regulation in determining the variety, quality and price of telecommunications services and that the economic burdens of regulation should be reduced to the extent possible consistent with the furtherance of market competition and protection of the public interest;

(c) all necessary and appropriate modifications to State regulation of telecommunications carriers and services should be implemented without unnecessary disruption to the telecommunications infrastructure system or to consumers of telecommunications services and that it is necessary and appropriate to establish rules to encourage and ensure orderly transitions in the development of markets for all telecommunications services;

(d) the consumers of telecommunications services and facilities provided by persons or companies subject to regulation pursuant to this Act and Article should be required to pay only reasonable and non-discriminatory rates or charges and that in no case should rates or charges for non-competitive telecommunications services include any portion of the cost of providing competitive telecommunications services, as defined in Section 13-209, or the cost of any nonregulated activities;

(e) the regulatory policies and procedures provided in this Article are established in recognition of the changing nature of the telecommunications industry and therefore should be subject to systematic legislative review to ensure that the public benefits intended to result from such policies and procedures are fully realized;

(f) development of and prudent investment in advanced telecommunications services and networks that foster economic development of the State should be encouraged through the implementation and enforcement of policies that promote effective and sustained competition in all telecommunications service markets; and

(g) completion of the transition to modern IP-based networks should be encouraged through relief from the outdated regulations that require continued investment in legacy circuit switched networks from which Illinois consumers have largely transitioned, while at the same time ensuring that consumers have access to available alternative services that provide quality voice service and access to emergency communications.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-201) (from Ch. 111 2/3, par. 13-201)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-201. Unless otherwise specified, the terms set forth in the following Sections preceding Section 13-301 of this Article are used in this Act and Article as herein defined.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-202) (from Ch. 111 2/3, par. 13-202)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-202. "Telecommunications carrier" means and includes every corporation, company, association, joint stock company or association, firm, partnership or individual, their lessees, trustees or receivers appointed by any court whatsoever that owns, controls, operates or manages, within this State, directly or indirectly, for public use, any plant, equipment or property used or to be used for or in connection with, or owns or controls any franchise, license, permit or right to engage in the provision of, telecommunications services between points within the State which are specified by the user. "Telecommunications carrier" includes an Electing Provider, as defined in Section 13-506.2. Telecommunications carrier does not include, however:

(a) telecommunications carriers that are owned and operated by any political subdivision, public or private institution of higher education or municipal corporation of this State, for their own use, or telecommunications carriers that are owned by such political subdivision, public or private institution of higher education, or municipal corporation and operated by any of its lessees or operating agents, for their own use;

(b) telecommunications carriers which are purely mutual concerns, having no rates or charges for services, but paying the operating expenses by assessment upon the members of such a company and no other person but does include telephone or telecommunications cooperatives as defined in Section 13-212;

(c) a company or person which provides telecommunications services solely to itself and its affiliates or members or between points in the same building, or between closely located buildings, affiliated through substantial common ownership, control or development; or

(d) a company or person engaged in the delivery of community antenna television services as described in subdivision (c) of Section 13-203, except with respect to the provision of telecommunications services by that company or person.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-202.5)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-202.5. Incumbent local exchange carrier. "Incumbent local exchange carrier" means, with respect to an area, the telecommunications carrier that provided noncompetitive local exchange telecommunications service in that area on February 8, 1996, and on that date was deemed a member of the exchange carrier association pursuant to 47 C.F.R. 69.601(b), and includes its successors, assigns, and affiliates.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-203) (from Ch. 111 2/3, par. 13-203)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-203. Telecommunications service. "Telecommunications service" means the provision or offering for rent, sale or lease, or in exchange for other value received, of the transmittal of information, by means of electromagnetic, including light, transmission with or without benefit of any closed transmission medium, including all instrumentalities, facilities, apparatus, and services (including the collection, storage, forwarding, switching, and delivery of such information) used to provide such transmission and also includes access and interconnection arrangements and services.

"Telecommunications service" does not include, however:

(a) the rent, sale, or lease, or exchange for other value received, of customer premises equipment except for customer premises equipment owned or provided by a telecommunications carrier and used for answering 911 calls, and except for customer premises equipment provided under Section 13-703;

(b) telephone or telecommunications answering services, paging services, and physical pickup and delivery incidental to the provision of information transmitted through electromagnetic, including light, transmission;

(c) community antenna television service which is operated to perform for hire the service of receiving and distributing video and audio program signals by wire, cable or other means to members of the public who subscribe to such service, to the extent that such service is utilized solely for the one-way distribution of such entertainment services with no more than incidental subscriber interaction required for the selection of such entertainment service.

The Commission may, by rulemaking, exclude (1) private line service which is not directly or indirectly used for the origination or termination of switched telecommunications service, (2) cellular radio service, (3) high-speed point-to-point data transmission at or above 9.6 kilobits, or (4) the provision of telecommunications service by a company or person otherwise subject to Section 13-202 (c) to a telecommunications carrier, which is incidental to the provision of service subject to Section 13-202 (c), from active regulatory oversight to the extent it finds, after notice, hearing and comment that such exclusion is consistent with the public interest and the purposes and policies of this Article. To the extent that the Commission has excluded cellular radio service from active regulatory oversight for any provider of cellular radio service in this State pursuant to this Section, the Commission shall exclude all other providers of cellular radio service in the State from active regulatory oversight without an additional rulemaking proceeding where there are 2 or more certified providers of cellular radio service in a geographic area.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-204) (from Ch. 111 2/3, par. 13-204)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-204. "Local Exchange Telecommunications Service" means telecommunications service between points within an exchange, as defined in Section 13-206, or the provision of telecommunications service for the origination or termination of switched telecommunications services.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-205) (from Ch. 111 2/3, par. 13-205)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-205. "Interexchange Telecommunications Service" means telecommunications service between points in two or more exchanges.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-206) (from Ch. 111 2/3, par. 13-206)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-206. Exchange. "Exchange" means a geographical area for the administration of telecommunications services, established and described by the tariff of a telecommunications carrier providing local exchange telecommunications service, and consisting of one or more contiguous central offices, together with associated facilities used in providing such local exchange telecommunications service. To the extent practicable, a municipality, city, or village shall not be located in more than one exchange unless the municipality, city, or village is located in more than one exchange through annexation that occurs after the establishment of the exchange boundary.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-207) (from Ch. 111 2/3, par. 13-207)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-207. "Local Access and Transport Area (LATA)" means a geographical area designated by the Modification of Final Judgment in U.S. v. Western Electric Co., Inc., 552 F. Supp. 131 (D.D.C. 1982), as modified from time to time.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-208) (from Ch. 111 2/3, par. 13-208)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-208. "Market Service Area (MSA)" means a geographical area consisting of one or more exchanges, defined by the Commission for the administration of tariffs, services and other regulatory obligations. The term Market Service Area includes those areas previously designated by the Commission.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-209) (from Ch. 111 2/3, par. 13-209)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-209. "Competitive Telecommunications Service" means a telecommunications service, its functional equivalent or a substitute service, which, for some identifiable class or group of customers in an exchange, group of exchanges, or some other clearly defined geographical area, is reasonably available from more than one provider, whether or not such provider is a telecommunications carrier subject to regulation under this Act. A telecommunications service may be competitive for the entire state, some geographical area therein, including an exchange or set of exchanges, or for a specific customer or class or group of customers, but only to the extent consistent with this definition.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-210) (from Ch. 111 2/3, par. 13-210)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-210. "Noncompetitive Telecommunications Service" means a telecommunications service other than a competitive service as defined in Section 13-209.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-211) (from Ch. 111 2/3, par. 13-211)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-211. "Resale of Telecommunications Service" means the offering or provision of telecommunications service primarily through the use of services or facilities owned or provided by a separate telecommunications carrier.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-212) (from Ch. 111 2/3, par. 13-212)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-212. "Telephone or Telecommunications Cooperative" means any Illinois corporation organized on a cooperative basis for the furnishing of telephone or telecommunications service.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-213) (from Ch. 111 2/3, par. 13-213)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-213. "Hearing-aid compatible telephone" means a telephone so equipped that it can activate an inductive coupling hearing-aid or which will provide an alternative technology that provides equally effective telephone service and which will provide equipment necessary for the hearing impaired to use generally available telecommunications services effectively or without assistance.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-214) (from Ch. 111 2/3, par. 13-214)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-214. (a) "Public mobile services" means air-to-ground radio telephone services, cellular radio telecommunications services, offshore radio, rural radio service, public land mobile telephone service and other common carrier radio communications services.

(b) "Private radio services" means private land mobile radio services and other communications services characterized by the Commission as private radio services.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-215) (from Ch. 111 2/3, par. 13-215)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-215. (a) "Essential telephones" means all coin operated telephones in any public or semi-public location, telephones provided for emergency use, a reasonable percentage of telephones in hotels, motels, hospitals and nursing homes and a reasonable percentage of credit card operated telephones in any group of such telephones.

(b) "Emergency use telephones" includes all telephones intended primarily to save persons from bodily injury, theft or life threatening situations. This definition includes, but is not limited to telephones in elevators, on highways and telephones to alert police, a fire department or other emergency service providers.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-216)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-216. Network element. "Network element" means a facility or equipment used in the provision of a telecommunications service. The term also includes features, functions, and capabilities that are provided by means of the facility or equipment, including, but not limited to, subscriber numbers, databases, signaling systems, and information sufficient for billing and collection or used in the transmission, routing, or other provision of a telecommunications service.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-217)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-217. End user. "End user" means any person, corporation, partnership, firm, municipality, cooperative, organization, governmental agency, building owner, or other entity provided with a telecommunications service for its own consumption and not for resale.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-218)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-218. Business end user. "Business end user" means (1) an end user engaged primarily or substantially in a paid commercial, professional, or institutional activity; (2) an end user provided telecommunications service in a commercial, professional, or institutional location, or other location serving primarily or substantially as a site of an activity for pay; (3) an end user whose telecommunications service is listed as the principal or only number for a business in any yellow pages directory; (4) an end user whose telecommunications service is used to conduct promotions, solicitations, or market research for which compensation or reimbursement is paid or provided; provided, however, that the use of telecommunications service, without compensation or reimbursement, for a charitable or civic purpose shall not constitute business use of a telecommunications service.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-219)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-219. Residential end user. "Residential end user" means an end user other than a business end user.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-220)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-220. Retail telecommunications service. "Retail telecommunications service" means a telecommunications service sold to an end user. "Retail telecommunications service" does not include a telecommunications service provided by a telecommunications carrier to a telecommunications carrier, including to itself, as a component of, or for the provision of, telecommunications service. A business retail telecommunications service is a retail telecommunications service provided to a business end user. A residential retail telecommunications service is a retail telecommunications service provided to a residential end user.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-230)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-230. Prepaid calling service. "Prepaid calling service" means telecommunications service that must be paid for in advance by an end user, enables the end user to originate calls using an access number or authorization code, whether manually or electronically dialed, and is sold in predetermined units or dollars of which the number declines with use in a known amount. A prepaid calling service call is a call made by an end user using prepaid calling service. "Prepaid calling service" does not include a wireless telecommunications service that allows a caller to dial 9-1-1 to access the 9-1-1 system, which service must be paid for in advance, and is sold in predetermined units or dollars and the amount declines with use in a known amount.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-231)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-231. Prepaid calling service provider. "Prepaid calling service provider" means and includes every corporation, company, association, joint stock company or association, firm, partnership, or individual and their lessees, trustees, or receivers appointed by any court whatsoever that contracts directly with a telecommunications carrier to resell or offers to resell telecommunications service as prepaid calling service to one or more distributors, prepaid calling resellers, prepaid calling service retailers, or end users.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-232)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-232. Prepaid calling service retailer. "Prepaid calling service retailer" means and includes every corporation, company, association, joint stock company or association, firm, partnership, or individual and their lessees, trustees, or receivers appointed by any court whatsoever that sells or offers to sell prepaid calling service directly to one or more end users.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-233)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-233. Prepaid calling service reseller. "Prepaid calling service reseller" means and includes every corporation, company, association, joint stock company or association, firm, partnership, or individual and their lessees, trustees, or receivers appointed by any court whatsoever that purchases prepaid calling services from a prepaid calling service provider or distributor and sells those services to one or more distributors of prepaid calling services or to one or more prepaid calling service retailers.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-234)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-234. Interconnected voice over Internet protocol service. "Interconnected voice over Internet protocol service" or "Interconnected VoIP service" has the meaning prescribed in 47 CFR 9.3 as defined on the effective date of this amendatory Act of the 96th General Assembly or as amended thereafter.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-235)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-235. Interconnected voice over Internet protocol provider. "Interconnected voice over Internet protocol provider" or "Interconnected VoIP provider" means and includes every corporation, company, association, joint stock company or association, firm, partnership, or individual, their lessees, trustees, or receivers appointed by any court whatsoever that owns, controls, operates, manages, or provides within this State, directly or indirectly, Interconnected voice over Internet protocol service.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-301) (from Ch. 111 2/3, par. 13-301)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-301. Duties of the Commission.

(1) Consistent with the findings and policy established in paragraph (a) of Section 13-102 and paragraph (a) of Section 13-103, and in order to ensure the attainment of such policies, the Commission shall:

(a) participate in all federal programs intended to preserve or extend universal telecommunications service, unless such programs would place cost burdens on Illinois customers of telecommunications services in excess of the benefits they would receive through participation, provided, however, the Commission shall not approve or permit the imposition of any surcharge or other fee designed to subsidize or provide a waiver for subscriber line charges; and shall report on such programs together with an assessment of their adequacy and the advisability of participating therein in its annual report to the General Assembly, or more often as necessary;

(b) (blank);

(c) order all telecommunications carriers offering or providing local exchange telecommunications service to propose low-cost or budget service tariffs and any other rate design or pricing mechanisms designed to facilitate customer access to such telecommunications service, provided that services offered by any telecommunications carrier at the rates, terms, and conditions specified in Section 13-506.2 or Section 13-518 of this Article shall constitute compliance with this Section. A telecommunications carrier may seek Commission approval of other low-cost or budget service tariffs or rate design or pricing mechanisms to comply with this Section;

(d) investigate the necessity of and, if appropriate, establish a universal service support fund from which local exchange telecommunications carriers who pursuant to the Twenty-Seventh Interim Order of the Commission in Docket No. 83-0142 or the orders of the Commission in Docket No. 97-0621 and Docket No. 98-0679 received funding and whose economic costs of providing services for which universal service support may be made available exceed the affordable rate established by the Commission for such services may be eligible to receive support, less any federal universal service support received for the same or similar costs of providing the supported services; provided, however, that if a universal service support fund is established, the Commission shall require that all costs of the fund be recovered from all local exchange and interexchange telecommunications carriers certificated in Illinois on a competitively neutral and nondiscriminatory basis. In establishing any such universal service support fund, the Commission shall, in addition to the determination of costs for supported services, consider and make findings pursuant to subsection (2) of this Section. Proxy cost, as determined by the Commission, may be used for this purpose. In determining cost recovery for any universal service support fund, the Commission shall not permit recovery of such costs from another certificated carrier for any service purchased and used solely as an input to a service provided to such certificated carrier's retail customers.

(2) In any order creating a fund pursuant to paragraph (d) of subsection (1), the Commission, after notice and hearing, shall:

(a) Define the group of services to be declared "supported telecommunications services" that constitute "universal service". This group of services shall, at a minimum, include those services as defined by the Federal Communications Commission and as from time to time amended. In addition, the Commission shall consider the range of services currently offered by telecommunications carriers offering local exchange telecommunications service, the existing rate structures for the supported telecommunications services, and the telecommunications needs of Illinois consumers in determining the supported telecommunications services. The Commission shall, from time to time or upon request, review and, if appropriate, revise the group of Illinois supported telecommunications services and the terms of the fund to reflect changes or enhancements in telecommunications needs, technologies, and available services.

(b) Identify all implicit subsidies contained in rates or charges of incumbent local exchange carriers, including all subsidies in interexchange access charges, and determine how such subsidies can be made explicit by the creation of the fund.

(c) Establish an affordable price for the supported telecommunications services for the respective incumbent local exchange carrier. The affordable price shall be no less than the rates in effect at the time the Commission creates a fund pursuant to this item. The Commission may establish and utilize indices or models for updating the affordable price for supported telecommunications services.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-301.1) (from Ch. 111 2/3, par. 13-301.1)

(Section scheduled to be repealed on January 1, 2025)

Sec. 13-301.1. Universal Telephone Service Assistance Program.

(a) The Commission shall by rule or regulation establish a Universal Telephone Service Assistance Program for low income residential customers. The program shall provide for a reduction of access line charges, a reduction of connection charges, or any other alternative assistance or program to increase accessibility to telephone service and broadband Internet access service that the Commission deems advisable subject to the availability of funds for the program as provided in subsections (d) and (e). The Commission shall establish eligibility requirements for benefits under the program.

(b) The Commission shall adopt rules providing for enhanced enrollment for eligible consumers to receive lifeline service. Enhanced enrollment may include, but is not limited to, joint marketing, joint application, or joint processing with the Low-Income Home Energy Assistance Program, the Medicaid Program, and the Food Stamp Program. The Department of Human Services, the Department of Healthcare and Family Services, and the Department of Commerce and Economic Opportunity, upon request of the Commission, shall assist in the adoption and implementation of those rules. The Commission and the Department of Human Services, the Department of Healthcare and Family Services, and the Department of Commerce and Economic Opportunity may enter into memoranda of understanding establishing the respective duties of the Commission and the Departments in relation to enhanced enrollment.

(c) In this Section:

"Lifeline service" means a retail local service offering described by 47 CFR 54.401(a), as amended.

(d) The Commission shall require by rule or regulation that each telecommunications carrier providing local exchange telecommunications services notify its customers that if the customer wishes to participate in the funding of the Universal Telephone Service Assistance Program he may do so by electing to contribute, on a monthly basis, a fixed amount that will be included in the customer's monthly bill. The customer may cease contributing at any time upon providing notice to the telecommunications carrier providing local exchange telecommunications services. The notice shall state that any contribution made will not reduce the customer's bill for telecommunications services. Failure to remit the amount of increased payment will reduce the contribution accordingly. The Commission shall specify the monthly fixed amount or amounts that customers wishing to contribute to the funding of the Universal Telephone Service Assistance Program may choose from in making their contributions. Every telecommunications carrier providing local exchange telecommunications services shall remit the amounts contributed in accordance with the terms of the Universal Telephone Service Assistance Program.

(e) Amounts collected and remitted under subsection (d) may, to the extent the Commission deems advisable, be used for funding a program to be administered by the entity designated by the Commission as administrator of the Universal Telephone Service Assistance Program for educating and assisting low-income residential customers with a transition to Internet protocol-based networks and services. This program may include, but need not be limited to, measures designed to notify and educate residential customers regarding the availability of alternative voice services with access to 9-1-1, access to and use of broadband Internet access service, and pricing options.

(Source: P.A. 100-20, eff. 7-1-17. Repealed by P.A. 103-826, eff. 1-1-25.)

(220 ILCS 5/13-301.2)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-301.2. Program to Foster Elimination of the Digital Divide. The Commission shall require by rule that each telecommunications carrier providing local exchange telecommunications service notify its end-user customers that if the customer wishes to participate in the funding of the Program to Foster Elimination of the Digital Divide he or she may do so by electing to contribute, on a monthly basis, a fixed amount that will be included in the customer's monthly bill. The obligations imposed in this Section shall not be imposed upon a telecommunications carrier for any of its end-users subscribing to the services listed below: (1) private line service which is not directly or indirectly used for the origination or termination of switched telecommunications service, (2) cellular radio service, (3) high-speed point-to-point data transmission at or above 9.6 kilobits, (4) the provision of telecommunications service by a company or person otherwise subject to subsection (c) of Section 13-202 to a telecommunications carrier, which is incidental to the provision of service subject to subsection (c) of Section 13-202; (5) pay telephone service; or (6) interexchange telecommunications service. The customer may cease contributing at any time upon providing notice to the telecommunications carrier. The notice shall state that any contribution made will not reduce the customer's bill for telecommunications services. Failure to remit the amount of increased payment will reduce the contribution accordingly. The Commission shall specify the monthly fixed amount or amounts that customers wishing to contribute to the funding of the Program to Foster Elimination of the Digital Divide may choose from in making their contributions. A telecommunications carrier subject to this obligation shall remit the amounts contributed by its customers to the Department of Commerce and Economic Opportunity for deposit in the Digital Divide Elimination Fund at the intervals specified in the Commission rules.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-301.3)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-301.3. Digital Divide Elimination Infrastructure Program.

(a) The Digital Divide Elimination Infrastructure Fund is created as a special fund in the State treasury. All moneys in the Fund shall be used, subject to appropriation, by the Commission to fund (i) the construction of facilities specified in Commission rules adopted under this Section and (ii) the accessible electronic information program, as provided in Section 20 of the Accessible Electronic Information Act. The Commission may accept private and public funds, including federal funds, for deposit into the Fund. Earnings attributable to moneys in the Fund shall be deposited into the Fund.

(b) The Commission shall adopt rules under which it will make grants out of funds appropriated from the Digital Divide Elimination Infrastructure Fund to eligible entities as specified in the rules for the construction of high-speed data transmission facilities in eligible areas of the State. For purposes of determining whether an area is an eligible area, the Commission shall consider, among other things, whether (i) in such area, advanced telecommunications services, as defined in subsection (c) of Section 13-517 of this Act, are under-provided to residential or small business end users, either directly or indirectly through an Internet Service Provider, (ii) such area has a low population density, and (iii) such area has not yet developed a competitive market for advanced services. In addition, if an entity seeking a grant of funds from the Digital Divide Elimination Infrastructure Fund is an incumbent local exchange carrier having the duty to serve such area, and the obligation to provide advanced services to such area pursuant to Section 13-517 of this Act, the entity shall demonstrate that it has sought and obtained an exemption from such obligation pursuant to subsection (b) of Section 13-517. Any entity seeking a grant of funds from the Digital Divide Elimination Infrastructure Fund shall demonstrate to the Commission that the grant shall be used for the construction of high-speed data transmission facilities in an eligible area and demonstrate that it satisfies all other requirements of the Commission's rules. The Commission shall determine the information that it deems necessary to award grants pursuant to this Section.

(c) The rules of the Commission shall provide for the competitive selection of recipients of grant funds available from the Digital Divide Elimination Infrastructure Fund pursuant to the Illinois Procurement Code. Grants shall be awarded to bidders chosen on the basis of the criteria established in such rules.

(d) All entities awarded grant moneys under this Section shall maintain all records required by Commission rule for the period of time specified in the rules. Such records shall be subject to audit by the Commission, by any auditor appointed by the State, or by any State officer authorized to conduct audits.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-302) (from Ch. 111 2/3, par. 13-302)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-302. (a) No telecommunications carrier shall implement a local measured service calling plan which does not include one of the following elements:

(1) the residential customer has the option of a flat rate local calling service under which local calls are not charged for frequency or duration; or

(2) residential calls to points within an untimed calling zone approved by the Commission are not charged for duration; or

(3) a low income residential Universal Service Assistance Program, which meets criteria set forth by the Commission, is available.

(b) In formulating the criteria for the low income residential Universal Service Assistance Program referred to in paragraph (3) of subsection (a), the Commission shall consider the desirability of various alternatives, including a reduction of the access line charge or connection charge for eligible customers.

(c) For local measured service plans implemented prior to the effective date of this amendatory Act of 1987 which do not contain one of the elements specified in paragraph (1) or (2) of subsection (a) of this Section, the Commission shall order the telecommunications carrier having such a plan to include one of the elements specified in paragraph (1) or (2) of subsection (a) of this Section by January 1, 1989.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-303)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-303. Action to enforce law or orders. Whenever the Commission is of the opinion that a telecommunications carrier is failing or omitting, or is about to fail or omit, to do anything required of it by law or by an order, decision, rule, regulation, direction, or requirement of the Commission or is doing or permitting anything to be done, or is about to do anything or is about to permit anything to be done, contrary to or in violation of law or an order, decision, rule, regulation, direction, or requirement of the Commission, the Commission shall file an action or proceeding in the circuit court in and for the county in which the case or some part thereof arose or in which the telecommunications carrier complained of has its principal place of business, in the name of the People of the State of Illinois for the purpose of having the violation or threatened violation stopped and prevented either by mandamus or injunction. The Commission may express its opinion in a resolution based upon whatever factual information has come to its attention and may issue the resolution ex parte and without holding any administrative hearing before bringing suit. Except in cases involving an imminent threat to the public health and safety, no such resolution shall be adopted until 48 hours after the telecommunications carrier has been given notice of (i) the substance of the alleged violation, including citation to the law, order, decision, rule, regulation, or direction of the Commission alleged to have been violated and (ii) the time and the date of the meeting at which such resolution will first be before the Commission for consideration.

The Commission shall file the action or proceeding by complaint in the circuit court alleging the violation or threatened violation complained of and praying for appropriate relief by way of mandamus or injunction. It shall be the duty of the court to specify a time, not exceeding 20 days after the service of the copy of the complaint, within which the telecommunications carrier complained of must answer the complaint, and in the meantime the telecommunications carrier may be restrained. In case of default in answer or after answer, the court shall immediately inquire into the facts and circumstances of the case. The telecommunications carrier and persons that the court may deem necessary or proper may be joined as parties. The final judgment in any action or proceeding shall either dismiss the action or proceeding or grant relief by mandamus or injunction as prayed for in the complaint, or in such modified or other form as will afford appropriate relief in the court's judgment.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-303.5)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-303.5. Injunctive relief. If, after a hearing, the Commission determines that a telecommunications carrier has violated this Act or a Commission order or rule, any telecommunications carrier adversely affected by the violation may seek injunctive relief in circuit court.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-304)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-304. Action to recover civil penalties.

(a) The Commission shall assess and collect all civil penalties established under this Act against telecommunications carriers, corporations other than telecommunications carriers, and persons acting as telecommunications carriers. Except for the penalties provided under Section 2-202, civil penalties may be assessed only after notice and opportunity to be heard. Any such civil penalty may be compromised by the Commission. In determining the amount of the civil penalty to be assessed, or the amount of the civil penalty to be compromised, the Commission is authorized to consider any matters of record in aggravation or mitigation of the penalty, including but not limited to the following:

(1) the duration and gravity of the violation of the Act, the rules, or the order of the Commission;

(2) the presence or absence of due diligence on the part of the violator in attempting either to comply with requirements of the Act, the rules, or the order of the Commission, or to secure lawful relief from those requirements;

(3) any economic benefits accrued by the violator because of the delay in compliance with requirements of the Act, the rules, or the order of the Commission; and

(4) the amount of monetary penalty that will serve to deter further violations by the violator and to otherwise aid in enhancing voluntary compliance with the Act, the rules, or the order of the Commission by the violator and other persons similarly subject to the Act.

(b) If timely judicial review of a Commission order that imposes a civil penalty is taken by a telecommunications carrier, a corporation other than a telecommunications carrier, or a person acting as a telecommunications carrier on whom or on which the civil penalty has been imposed, the reviewing court shall enter a judgment on all amounts upon affirmance of the Commission order. If timely judicial review is not taken and the civil penalty remains unpaid for 60 days after service of the order, the Commission in its discretion may either begin revocation proceedings or bring suit to recover the penalties. Unless stayed by a reviewing court, interest shall accrue from the 60th day after the date of service of the Commission order to the date full payment is received by the Commission.

(c) Actions to recover delinquent civil penalties under this Section shall be brought in the name of the People of the State of Illinois in the circuit court in and for the county in which the cause, or some part thereof, arose, or in which the entity complained of resides. The action shall be commenced and prosecuted to final judgement by the Commission. In any such action, all interest incurred up to the time of final court judgment may be recovered in that action. In all such actions, the procedure and rules of evidence shall be the same as in ordinary civil actions, except as otherwise herein provided. Any such action may be compromised or discontinued on application of the Commission upon such terms as the court shall approve and order.

(d) Civil penalties related to the late filing of reports, taxes, or other filings shall be paid into the State treasury to the credit of the Public Utility Fund. Except as otherwise provided in this Act, all other fines and civil penalties shall be paid into the State treasury to the credit of the General Revenue Fund.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-305)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-305. Amount of civil penalty. A telecommunications carrier, any corporation other than a telecommunications carrier, or any person acting as a telecommunications carrier that violates or fails to comply with any provisions of this Act or that fails to obey, observe, or comply with any order, decision, rule, regulation, direction, or requirement, or any part or provision thereof, of the Commission, made or issued under authority of this Act, in a case in which a civil penalty is not otherwise provided for in this Act, but excepting Section 5-202 of the Act, shall be subject to a civil penalty imposed in the manner provided in Section 13-304 of no more than $30,000 or 0.00825% of the carrier's gross intrastate annual telecommunications revenue, whichever is greater, for each offense unless the violator has fewer than 35,000 subscriber access lines, in which case the civil penalty may not exceed $2,000 for each offense.

A telecommunications carrier subject to administrative penalties resulting from a final Commission order approving an intercorporate transaction entered pursuant to Section 7-204 of this Act shall be subject to penalties under this Section imposed for the same conduct only to the extent that such penalties exceed those imposed by the final Commission order.

Every violation of the provisions of this Act or of any order, decision, rule, regulation, direction, or requirement of the Commission, or any part or provision thereof, by any corporation or person, is a separate and distinct offense. Penalties under this Section shall attach and begin to accrue from the day after written notice is delivered to such party or parties that they are in violation of or have failed to comply with this Act or an order, decision, rule, regulation, direction, or requirement of the Commission, or part or provision thereof. In case of a continuing violation, each day's continuance thereof shall be a separate and distinct offense.

In construing and enforcing the provisions of this Act relating to penalties, the act, omission, or failure of any officer, agent, or employee of any telecommunications carrier or of any person acting within the scope of his or her duties or employment shall in every case be deemed to be the act, omission, or failure of such telecommunications carrier or person.

If the party who has violated or failed to comply with this Act or an order, decision, rule, regulation, direction, or requirement of the Commission, or any part or provision thereof, fails to seek timely review pursuant to Sections 10-113 and 10-201 of this Act, the party shall, upon expiration of the statutory time limit, be subject to the civil penalty provision of this Section.

Twenty percent of all moneys collected under this Section shall be deposited into the Digital Divide Elimination Fund and 20% of all moneys collected under this Section shall be deposited into the Digital Divide Elimination Infrastructure Fund.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-401) (from Ch. 111 2/3, par. 13-401)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-401. Certificate of Service Authority.

(a) No telecommunications carrier not possessing a certificate of public convenience and necessity or certificate of authority from the Commission at the time this Article goes into effect shall transact any business in this State until it shall have obtained a certificate of service authority from the Commission pursuant to the provisions of this Article.

No telecommunications carrier offering or providing, or seeking to offer or provide, any interexchange telecommunications service shall do so until it has applied for and received a Certificate of Interexchange Service Authority pursuant to the provisions of Section 13-403. No telecommunications carrier offering or providing, or seeking to offer or provide, any local exchange telecommunications service shall do so until it has applied for and received a Certificate of Exchange Service Authority pursuant to the provisions of Section 13-405.

Notwithstanding Sections 13-403, 13-404, and 13-405, the Commission shall approve a cellular radio application for a Certificate of Service Authority without a hearing upon a showing by the cellular applicant that the Federal Communications Commission has issued to it a construction permit or an operating license to construct or operate a cellular radio system in the area as defined by the Federal Communications Commission, or portion of the area, for which the carrier seeks a Certificate of Service Authority.

No Certificate of Service Authority issued by the Commission shall be construed as granting a monopoly or exclusive privilege, immunity or franchise. The issuance of a Certificate of Service Authority to any telecommunications carrier shall not preclude the Commission from issuing additional Certificates of Service Authority to other telecommunications carriers providing the same or equivalent service or serving the same geographical area or customers as any previously certified carrier, except to the extent otherwise provided by Sections 13-403 and 13-405.

Any certificate of public convenience and necessity granted by the Commission to a telecommunications carrier prior to the effective date of this Article shall remain in full force and effect, and such carriers need not apply for a Certificate of Service Authority in order to continue offering or providing service to the extent authorized in such certificate of public convenience and necessity. Any such carrier, however, prior to substantially altering the nature or scope of services provided under a certificate of public convenience and necessity, or adding or expanding services beyond the authority contained in such certificate, must apply for a Certificate of Service Authority for such alterations or additions pursuant to the provisions of this Article.

The Commission shall review and modify the terms of any certificate of public convenience and necessity issued to a telecommunications carrier prior to the effective date of this Article in order to ensure its conformity with the requirements and policies of this Article. Any Certificate of Service Authority may be altered or modified by the Commission, after notice and hearing, upon its own motion or upon application of the person or company affected. Unless exercised within a period of two years from the issuance thereof, authority conferred by a Certificate of Service Authority shall be null and void.

(b) The Commission may issue a temporary Certificate which shall remain in force not to exceed one year in cases of emergency, to assure maintenance of adequate service or to serve particular customers, without notice and hearing, pending the determination of an application for a Certificate, and may by regulation exempt from the requirements of this Section temporary acts or operations for which the issuance of a certificate is not necessary in the public interest and which will not be required therefor.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-401.1)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-401.1. Interconnected voice over Internet protocol (VoIP) service surcharge. An interconnected voice over Internet protocol provider shall charge and collect from its end-user customers, and remit to the appropriate authority, fees and surcharges in the same manner as are charged and collected upon end-user customers of local exchange telecommunications service and remitted by local exchange telecommunications companies for local enhanced 9-1-1 surcharges.

(Source: P.A. 100-20, eff. 7-1-17; 100-840, eff. 8-13-18.)

(220 ILCS 5/13-402) (from Ch. 111 2/3, par. 13-402)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-402. The Commission is authorized, in connection with the issuance or modification of a Certificate of Interexchange Service Authority or the modification of a certificate of public convenience and necessity for interexchange telecommunications service, to waive or modify the application of its rules, general orders, procedures or notice requirements when such action will reduce the economic burdens of regulation and such waiver or modification is not inconsistent with the law or the purposes and policies of this Article.

Any such waiver or modification granted to any interexchange telecommunications carrier which has, or any group of such carriers any one of which has annual revenues exceeding $10,000,000 shall be automatically applied fully and equally to all such carriers with annual revenues exceeding $10,000,000 unless the Commission specifically finds, after notice to all such carriers and a hearing, that restricting the application of such waiver or modification to only one such carrier or some group of such carriers is consistent with and would promote the purposes and policies of this Article and the protection of telecommunications customers.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-402.1)

Sec. 13-402.1. (Repealed).

(Source: P.A. 87-856. Repealed by P.A. 96-927, eff. 6-15-10.)

(220 ILCS 5/13-403) (from Ch. 111 2/3, par. 13-403)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-403. Interexchange service authority; approval. The Commission shall approve an application for a Certificate of Interexchange Service Authority only upon a showing by the applicant, and a finding by the Commission, after notice and hearing, that the applicant possesses sufficient technical, financial and managerial resources and abilities to provide interexchange telecommunications service. The removal from this Section of the dialing restrictions by this amendatory Act of 1992 does not create any legislative presumption for or against intra-Market Service Area presubscription or changes in intra-Market Service Area dialing arrangements related to the implementation of that presubscription, but simply vests jurisdiction in the Illinois Commerce Commission to consider after notice and hearing the issue of presubscription in accordance with the policy goals outlined in Section 13-103.

The Commission shall have authority to alter the boundaries of Market Service Areas when such alteration is consistent with the public interest and the purposes and policies of this Article. A determination by the Commission with respect to Market Service Area boundaries shall not modify or affect the rights or obligations of any telecommunications carrier with respect to any consent decree or agreement with the United States Department of Justice, including, but not limited to, the Modification of Final Judgment in United States v. Western Electric Co., 552 F. Supp. 131 (D.D.C. 1982), as modified from time to time.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-404) (from Ch. 111 2/3, par. 13-404)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-404. Any telecommunications carrier offering or providing the resale of either local exchange or interexchange telecommunications service must first obtain a Certificate of Service Authority. The Commission shall approve an application for a Certificate for the resale of local exchange or interexchange telecommunications service upon a showing by the applicant, and a finding by the Commission, after notice and hearing, that the applicant possesses sufficient technical, financial and managerial resources and abilities to provide the resale of telecommunications service.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-404.1)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-404.1. Prepaid calling service authority; rules.

(a) The General Assembly finds that it is necessary to require the certification of prepaid calling service providers to protect and promote against fraud the legitimate business interests of persons or entities currently providing prepaid calling service to Illinois end users and Illinois end users who purchase these services.

(b) On and after July 1, 2005, it shall be unlawful for any prepaid calling service provider to offer or provide or seek to offer or provide to any distributor, prepaid calling service reseller, prepaid calling service retailer, or end user any prepaid calling service unless the prepaid calling service provider has applied for and received a Certificate of Prepaid Calling Service Provider Authority from the Commission. The Commission shall approve an application for a Certificate of Prepaid Calling Service Provider Authority upon a showing by the applicant, and a finding by the Commission, after notice and hearing, that the applicant possesses sufficient technical, financial, and managerial resources and abilities to provide prepaid calling services. The Commission shall approve an application for a Certificate of Prepaid Calling Service Provider Authority without a hearing upon a showing by the applicant that the Commission has issued an appropriate Certificate of Service Authority (whether a Certificate of Interexchange Service Authority or Certificate of Exchange Service Authority or both) to the applicant or the telecommunications carrier whose service the applicant is seeking to resell, provided that the telecommunications carrier remains in good standing with the Commission. The Commission may adopt rules necessary for the administration of this subsection.

(c) Upon issuance of a Certificate of Prepaid Calling Service Provider Authority to a prepaid calling service provider, the Commission shall post a list that contains the full legal name of the prepaid service provider, the docket number of the provider's certification proceeding, and the toll-free customer service number of the certified prepaid calling service provider on the Commission's web site on a link solely dedicated to prepaid calling service providers. If the certified prepaid calling service provider changes its toll-free customer service number, it is the duty of the certified prepaid calling service provider to provide the Commission with notice of the change and with the provider's new toll-free customer service number at least 24 hours prior to changing its toll-free customer service number. The Commission may adopt rules that further define the administration of this subsection.

(d) Any and all enforcement authority granted to the Commission under this Article over any Certificate of Service Authority shall apply equally and without limitation to Certificates of Prepaid Calling Service Provider Authority.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-404.2)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-404.2. Prepaid calling service standards. The Commission, by rule, may establish and implement minimum service quality standards for prepaid calling service. The rules may include, but are not limited to, requiring access to a live customer service attendant through the customer service number, reporting requirements, fines, penalties, customer credits, remedies, and other enforcement mechanisms to ensure compliance with the service quality standards.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-405) (from Ch. 111 2/3, par. 13-405)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-405. Local exchange service authority; approval. The Commission shall approve an application for a Certificate of Exchange Service Authority only upon a showing by the applicant, and a finding by the Commission, after notice and hearing, that the applicant possesses sufficient technical, financial, and managerial resources and abilities to provide local exchange telecommunications service.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-405.1) (from Ch. 111 2/3, par. 13-405.1)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-405.1. Interexchange services; incidental local service. Whether or not a telecommunications carrier is certified to offer or provide local exchange telecommunications service, nothing in Section 13-405 shall be construed to require the withdrawal or prevent the offering of interexchange services merely because incidental use of such service by the customer for local exchange telecommunications service is possible.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-406) (from Ch. 111 2/3, par. 13-406)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-406. Abandonment of service.

(a) No telecommunications carrier offering or providing noncompetitive telecommunications service pursuant to a valid Certificate of Service Authority or certificate of public convenience and necessity shall discontinue or abandon such service once initiated until and unless it shall demonstrate, and the Commission finds, after notice and hearing, that such discontinuance or abandonment will not deprive customers of any necessary or essential telecommunications service or access thereto and is not otherwise contrary to the public interest. No telecommunications carrier offering or providing competitive telecommunications service shall completely discontinue or abandon such service to an identifiable class or group of customers once initiated except upon 60 days' notice to the Commission and affected customers. The Commission may, upon its own motion or upon complaint, investigate the proposed discontinuance or abandonment of a competitive telecommunications service and may, after notice and hearing, prohibit such proposed discontinuance or abandonment if the Commission finds that it would be contrary to the public interest. If the Commission does not provide notice of a hearing within 60 calendar days after the notification or holds a hearing and fails to find that the proposed discontinuation or abandonment would be contrary to the public interest, the provider may discontinue or abandon such service after providing at least 30 days' notice to affected customers. This Section does not apply to a Large Electing Provider proceeding under Section 13-406.1.

(b) A Small Electing Provider may choose to cease offering or providing a telecommunications service pursuant to either this Section or Section 13-406.1 of this Act in the same manner as a Large Electing Provider. A Small Electing Provider that elects to cease offering or providing a telecommunications service pursuant to Section 13-406.1 shall be subject to all of the provisions that apply to a Large Electing Provider under Section 13-406.1. In this subsection (b), "Small Electing Provider" means an incumbent local exchange carrier, as defined in Section 13-202.5 of this Act, that is an Electing Provider, as defined in Section 13-506.2 of this Act, and that, together with all of its incumbent local exchange carrier affiliates offering telecommunications services within the State of Illinois, has fewer than 40,000 subscriber access lines as of January 1, 2020.

(Source: P.A. 102-9, eff. 6-3-21.)

(220 ILCS 5/13-406.1)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-406.1. Large Electing Provider transition to IP-based networks and service.

(a) As used in this Section:

"Alternative voice service" means service that includes all of the applicable functionalities for voice telephony services described in 47 CFR 54.101(a).

"Existing customer" means a residential customer of the Large Electing Provider who is subscribing to a telecommunications service on the date the Large Electing Provider sends its notice under paragraph (1) of subsection (c) of this Section of its intent to cease offering and providing service. For purposes of this Section, a residential customer of the Large Electing Provider whose service has been temporarily suspended, but not finally terminated as of the date that the Large Electing Provider sends that notice, shall be deemed to be an "existing customer".

"Large Electing Provider" means an Electing Provider, as defined in Section 13-506.2 of this Act, that (i) reported in its annual competition report for the year 2016 filed with the Commission under Section 13-407 of this Act and 83 Ill. Adm. Code 793 that it provided at least 700,000 access lines to end users; and (ii) is affiliated with a provider of commercial mobile radio service, as defined in 47 CFR 20.3, as of January 1, 2017.

"New customer" means a residential customer who is not subscribing to a telecommunications service provided by the Large Electing Provider on the date the Large Electing Provider sends its notice under paragraph (1) of subsection (c) of this Section of its intent to cease offering and providing that service.

"Provider" includes every corporation, company, association, firm, partnership, and individual and their lessees, trustees, or receivers appointed by a court that sell or offer to sell an alternative voice service.

"Reliable access to 9-1-1" means access to 9-1-1 that complies with the applicable rules, regulations, and guidelines established by the Federal Communications Commission and the applicable provisions of the Emergency Telephone System Act and implementing rules.

"Willing provider" means a provider that voluntarily participates in the request for service process.

(b) Beginning June 30, 2017, a Large Electing Provider may, to the extent permitted by and consistent with federal law, including, as applicable, approval by the Federal Communications Commission of the discontinuance of the interstate-access component of a telecommunications service, cease to offer and provide a telecommunications service to an identifiable class or group of customers, other than voice telecommunications service to residential customers or a telecommunications service to a class of customers under subsection (b-5) of this Section, upon 60 days' notice to the Commission and affected customers.

(b-5) Notwithstanding any provision to the contrary in this Section 13-406.1, beginning December 31, 2021, a Large Electing Provider may, to the extent permitted by and consistent with federal law, including, if applicable, approval by the Federal Communications Commission of the discontinuance of the interstate-access component of a telecommunication service, cease to offer and provide a telecommunications service to one or more of the following classes or groups of customers upon 60 days' notice to the Commission and affected customers: (1) electric utilities, as defined in Section 16-102 of this Act; (2) public utilities, as defined in Section 3-105 of this Act, that offers natural gas or water services; (3) electric, gas, and water utilities that are excluded from the definition of public utility under paragraph (1) of subsection (b) of Section 3-105 of this Act; (4) water companies as described in paragraph (2) of subsection (b) of Section 3-105 of this Act; (5) natural gas cooperatives as described in paragraph (4) of subsection (b) of Section 3-105 of this Act; (6) electric cooperatives as defined in Section 3-119 of this Act; (7) entities engaged in the commercial generation of electric power and energy; (8) the functional divisions of public agencies, as defined in Section 2 of the Emergency Telephone System Act, that provide police or firefighting services; and (9) 9-1-1 Authorities, as defined in Section 2 of the Emergency Telephone System Act; provided that the date shall be extended to December 21, 2022, for (i) an electric utility, as defined in Section 16-102 of this Act, that serves more than 3 million customers in the State; and (ii) an entity engaged in the commercial generation of electric power and energy that operates one or more nuclear power plants in the State.

(c) Beginning June 30, 2017, a Large Electing Provider may, to the extent permitted by and consistent with federal law, cease to offer and provide voice telecommunications service to an identifiable class or group of residential customers, which, for the purposes of this subsection (c), shall be referred to as "requested service", subject to compliance with the following requirements:

(1) No less than 255 days prior to providing notice to the Federal Communications Commission of its intent to discontinue the interstate-access component of the requested service, the Large Electing Provider shall:

(A) file a notice of the proposed cessation of the requested service with the Commission, which shall include a statement that the Large Electing Provider will comply with any service discontinuance rules and regulations of the Federal Communications Commission pertaining to compatibility of alternative voice services with medical monitoring devices; and

(B) provide notice of the proposed cessation of the requested service to each of the Large Electing Provider's existing customers within the affected geographic area by first-class mail separate from customer bills. If the customer has elected to receive electronic billing, the notice shall be sent electronically and by first-class mail separate from customer bills. The notice provided under this subparagraph (B) shall describe the requested service, identify the earliest date on which the Large Electing Provider intends to cease offering or providing the telecommunications service, provide a telephone number by which the existing customer may contact a service representative of the Large Electing Provider, and provide a telephone number by which the existing customer may contact the Commission's Consumer Services Division. The notice shall also include the following statement in English and in Spanish:

"If you do not believe that an alternative voice service including reliable access to 9-1-1 is available to you, from either [name of Large Electing Provider] or another provider of wired or wireless voice service where you live, you have the right to request the Illinois Commerce Commission to investigate the availability of alternative voice service including reliable access to 9-1-1. To do so, you must submit such a request either in writing or by signing and returning a copy of this notice, no later than (insert date), 60 days after the date of the notice to the following address:

Chief Clerk of the Illinois Commerce Commission

527 East Capitol Avenue

Springfield, Illinois 62706

You must include in your request a reference to the notice you received from [Large Electing Provider's name] and the date of notice.".

Thirty days following the date of notice, the Large Electing Provider shall provide each customer to which the notice was sent a follow-up notice containing the same information and reminding customers of the deadline for requesting the Commission to investigate alternative voice service with access to 9-1-1.

(2) After June 30, 2017, and only in a geographic area for which a Large Electing Provider has provided notice of proposed cessation of the requested service to existing customers under paragraph (1) of this subsection (c), an existing customer of that provider may, within 60 days after issuance of such notice, request the Commission to investigate the availability of alternative voice service including reliable access to 9-1-1 to that customer. For the purposes of this paragraph (2), existing customers who make such a request are referred to as "requesting existing customers". The Large Electing Provider may cease to offer or provide the requested service to existing customers who do not make a request for investigation beginning 30 days after issuance of the notice required by paragraph (5) of this subsection (c).

(A) In response to all requests and investigations under this paragraph (2), the Commission shall conduct a single investigation to be commenced 75 days after the receipt of notice under paragraph (1) of this subsection (c), and completed within 135 days after commencement. The Commission shall, within 135 days after commencement of the investigation, make one of the findings described in subdivisions (i) and (ii) of this subparagraph (A) for each requesting existing customer.

(i) If, as a result of the investigation, the Commission finds that service from at least one provider offering alternative voice service including reliable access to 9-1-1 through any technology or medium is available to one or more requesting existing customers, the Commission shall declare by order that, with respect to each requesting existing customer for which such a finding is made, the Large Electing Provider may cease to offer or provide the requested service beginning 30 days after the issuance of the notice required by paragraph (5) of this subsection (c).

(ii) If, as a result of the investigation, the Commission finds that service from at least one provider offering alternative voice service, including reliable access to 9-1-1, through any technology or medium is not available to one or more requesting existing customers, the Commission shall declare by order that an emergency exists with respect to each requesting existing customer for which such a finding is made.

(B) If the Commission declares an emergency under subdivision (ii) of subparagraph (A) of this paragraph (2) with respect to one or more requesting existing customers, the Commission shall conduct a request for service process to identify a willing provider of alternative voice service including reliable access to 9-1-1. A provider shall not be required to participate in the request for service process. The willing provider may utilize any form of technology that is capable of providing alternative voice service including reliable access to 9-1-1, including, without limitation, Voice over Internet Protocol services and wireless services. The Commission shall, within 45 days after the issuance of an order finding that an emergency exists, make one of the determinations described in subdivisions (i) and (ii) of this subparagraph (B) for each requesting existing customer for which an emergency has been declared.

(i) If the Commission determines that another provider is willing and capable of providing alternative voice service including reliable access to 9-1-1 to one or more requesting existing customers for which an emergency has been declared, the Commission shall declare by order that, with respect to each requesting existing customer for which such a determination is made, the Large Electing Provider may cease to offer or provide the requested service beginning 30 days after the issuance of the notice required by paragraph (5) of this Section.

(ii) If the Commission determines that for one or more of the requesting existing customers for which an emergency has been declared there is no other provider willing and capable of providing alternative voice service including reliable access to 9-1-1, the Commission shall issue an order requiring the Large Electing Provider to provide alternative voice service including reliable access to 9-1-1 to each requesting existing customer utilizing any form of technology capable of providing alternative voice service including reliable access to 9-1-1, including, without limitation, continuation of the requested service, Voice over Internet Protocol services, and wireless services, until another willing provider is available. A Large Electing Provider may fulfill the requirement through an affiliate or another provider. The Large Electing Provider may request that such an order be rescinded upon a showing that an alternative voice service including reliable access to 9-1-1 has become available to the requesting existing customer from another provider.

(3) If the Commission receives no requests for investigation from any existing customer under paragraph (2) of this subsection (c) within 60 days after issuance of the notice under paragraph (1) of this subsection (c), the Commission shall provide written notice to the Large Electing Provider of that fact no later than 75 days after receipt of notice under paragraph (1) of this subsection (c). Notwithstanding any provision of this subsection (c) to the contrary, if no existing customer requests an investigation under paragraph (2) of this subsection (c), the Large Electing Provider may immediately provide the notice to the Federal Communications Commission as described in paragraph (4) of this subsection (c).

(4) At the same time that it provides notice to the Federal Communications Commission of its intent to discontinue the interstate-access component of the requested service, the Large Electing Provider shall:

(A) file a notice of proposal to cease to offer and provide the requested service with the Commission; and

(B) provide a notice of proposal to cease to offer and provide the requested service to existing customers and new customers receiving the service at the time of the notice within each affected geographic area, with the notice made by first-class mail or within customer bills delivered by mail or equivalent means of notice, including electronic means if the customer has elected to receive electronic billing. The notice provided under this subparagraph (B) shall include a brief description of the requested service, the date on which the Large Electing Provider intends to cease offering or providing the telecommunications service, and a statement as required by 47 CFR 63.71 that describes the process by which the customer may submit comments to the Federal Communications Commission.

(5) Upon approval by the Federal Communications Commission of its request to discontinue the interstate-access component of the requested service and subject to the requirements of any order issued by the Commission under subdivision (ii) of subparagraph (B) of paragraph (2) of this subsection (c), the Large Electing Provider may immediately cease to offer the requested service to all customers not receiving the service on the date of the Federal Communications Commission's approval and may cease to offer and provide the requested service to all customers receiving the service at the time of the Federal Communications Commission's approval upon 30 days' notice to the Commission and affected customers. Notice to affected customers under this paragraph (5) shall be provided by first-class mail separate from customer bills. The notice provided under this paragraph (5) shall describe the requested service, identify the date on which the Large Electing Provider intends to cease offering or providing the telecommunications service, and provide a telephone number by which the existing customer may contact a service representative of the Large Electing Provider.

(6) The notices provided for in paragraph (1) of this subsection (c) are not required as a prerequisite for the Large Electing Provider to cease to offer or provide a telecommunications service in a geographic area where there are no residential customers taking service from the Large Electing Provider on the date that the Large Electing Provider files notice to the Federal Communications Commission of its intent to discontinue the interstate-access component of the requested service in that geographic area.

(7) For a period of 45 days following the date of a notice issued under paragraph (5) of this Section, an existing customer (i) who is located in the affected geographic area subject to that notice; (ii) who was receiving the requested service as of the date of the Federal Communications Commission's approval of the Large Electing Provider's request to discontinue the interstate-access component of the requested service; (iii) who did not make a timely request for investigation under paragraph (2) of this subsection (c); and (iv) whose service will be or has been discontinued under paragraph (5), may request assistance from the Large Electing Provider in identifying providers of alternative voice service including reliable access to 9-1-1. Within 15 days of the request, the Large Electing Provider shall provide the customer with a list of alternative voice service providers.

(8) Notwithstanding any other provision of this Act, except as expressly authorized by this subsection (c), the Commission may not, upon its own motion or upon complaint, investigate, suspend, disapprove, condition, or otherwise regulate the cessation of a telecommunications service to an identifiable class or group of customers once initiated by a Large Electing Provider under subsection (b) or (b-5) of this Section or this subsection (c).

(Source: P.A. 100-20, eff. 7-1-17; 100-719, eff. 8-3-18.)

(220 ILCS 5/13-407)

Sec. 13-407. (Repealed).

(Source: P.A. 100-20, eff. 7-1-17. Repealed by P.A. 100-840, eff. 8-13-18.)

(220 ILCS 5/13-408)

Sec. 13-408. (Repealed).

(Source: P.A. 93-5, eff. 5-9-03. Repealed by P.A. 96-927, eff. 6-15-10.)

(220 ILCS 5/13-409)

Sec. 13-409. (Repealed).

(Source: P.A. 93-521, eff. 8-9-03. Repealed by P.A. 96-927, eff. 6-15-10.)

(220 ILCS 5/13-501) (from Ch. 111 2/3, par. 13-501)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-501. Tariff; filing.

(a) No telecommunications carrier shall offer or provide noncompetitive telecommunications service, telecommunications service subject to subsection (g) of Section 13-506.2 or Section 13-900.1 or 13-900.2 of this Act, or telecommunications service referred to in an interconnection agreement as a tariffed service unless and until a tariff is filed with the Commission which describes the nature of the service, applicable rates and other charges, terms and conditions of service, and the exchange, exchanges or other geographical area or areas in which the service shall be offered or provided. The Commission may prescribe the form of such tariff and any additional data or information which shall be included therein.

(b) After a hearing regarding a telecommunications service subject to subsection (a) of this Section, the Commission has the discretion to impose an interim or permanent tariff on a telecommunications carrier as part of the order in the case. When a tariff is imposed as part of the order in a case, the tariff shall remain in full force and effect until a compliance tariff, or superseding tariff, is filed by the telecommunications carrier and, after notice to the parties in the case and after a compliance hearing is held, is found by the Commission to be in compliance with the Commission's order.

(c) A telecommunications carrier shall offer or provide telecommunications service that is not subject to subsection (a) of this Section pursuant to either a tariff filed with the Commission or a written service offering that shall be available on the telecommunications carrier's website as required by Section 13-503 of this Act and that describes the nature of the service, applicable rates and other charges, terms and conditions of service. Revenue from competitive retail telecommunications service received by a telecommunications carrier pursuant to either a tariff or a written service offering shall be gross revenue for purposes of Section 2-202 of this Act.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-501.5)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-501.5. Directory assistance service for the blind. A telecommunications carrier that provides directory assistance service shall provide in its tariffs or its written service offering pursuant to subsection (c) of Section 13-501 of this Act for that service that directory assistance shall be provided at no charge to its customers who are legally blind for telephone numbers of customers located within the same calling area, as described in the telecommunications carrier's tariff.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-502) (from Ch. 111 2/3, par. 13-502)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-502. Classification of services.

(a) All telecommunications services offered or provided under tariff by telecommunications carriers shall be classified as either competitive or noncompetitive. A telecommunications carrier may offer or provide either competitive or noncompetitive telecommunications services, or both, subject to proper certification and other applicable provisions of this Article. Any tariff filed with the Commission as required by Section 13-501 shall indicate whether the service to be offered or provided is competitive or noncompetitive.

(b) A service shall be classified as competitive only if, and only to the extent that, for some identifiable class or group of customers in an exchange, group of exchanges, or some other clearly defined geographical area, such service, or its functional equivalent, or a substitute service, is reasonably available from more than one provider, whether or not any such provider is a telecommunications carrier subject to regulation under this Act. All telecommunications services not properly classified as competitive shall be classified as noncompetitive. The Commission shall have the power to investigate the propriety of any classification of a telecommunications service on its own motion and shall investigate upon complaint. In any hearing or investigation, the burden of proof as to the proper classification of any service shall rest upon the telecommunications carrier providing the service. After notice and hearing, the Commission shall order the proper classification of any service in whole or in part. The Commission shall make its determination and issue its final order no later than 180 days from the date such hearing or investigation is initiated. If the Commission enters into a hearing upon complaint and if the Commission fails to issue an order within that period, the complaint shall be deemed granted unless the Commission, the complainant, and the telecommunications carrier providing the service agree to extend the time period.

(c) In determining whether a service should be reclassified as competitive, the Commission shall, at a minimum, consider the following factors:

(1) the number, size, and geographic distribution of other providers of the service;

(2) the availability of functionally equivalent services in the relevant geographic area and the ability of telecommunications carriers or other persons to make the same, equivalent, or substitutable service readily available in the relevant market at comparable rates, terms, and conditions;

(3) the existence of economic, technological, or any other barriers to entry into, or exit from, the relevant market;

(4) the extent to which other telecommunications companies must rely upon the service of another telecommunications carrier to provide telecommunications service; and

(5) any other factors that may affect competition and the public interest that the Commission deems appropriate.

(d) No tariff classifying a new telecommunications service as competitive or reclassifying a previously noncompetitive telecommunications service as competitive, which is filed by a telecommunications carrier which also offers or provides noncompetitive telecommunications service, shall be effective unless and until such telecommunications carrier offering or providing, or seeking to offer or provide, such proposed competitive service prepares and files a study of the long-run service incremental cost underlying such service and demonstrates that the tariffed rates and charges for the service and any relevant group of services that includes the proposed competitive service and for which resources are used in common solely by that group of services are not less than the long-run service incremental cost of providing the service and each relevant group of services. Such study shall be given proprietary treatment by the Commission at the request of such carrier if any other provider of the competitive service, its functional equivalent, or a substitute service in the geographical area described by the proposed tariff has not filed, or has not been required to file, such a study.

(e) In the event any telecommunications service has been classified and filed as competitive by the telecommunications carrier, and has been offered or provided on such basis, and the Commission subsequently determines after investigation that such classification improperly included services which were in fact noncompetitive, the Commission shall have the power to determine and order refunds to customers for any overcharges which may have resulted from the improper classification, or to order such other remedies provided to it under this Act, or to seek an appropriate remedy or relief in a court of competent jurisdiction.

(f) If no hearing or investigation regarding the propriety of a competitive classification of a telecommunications service is initiated within 180 days after a telecommunications carrier files a tariff listing such telecommunications service as competitive, no refunds to customers for any overcharges which may result from an improper classification shall be ordered for the period from the time the telecommunications carrier filed such tariff listing the service as competitive up to the time an investigation of the service classification is initiated by the Commission's own motion or the filing of a complaint. Where a hearing or an investigation regarding the propriety of a telecommunications service classification as competitive is initiated after 180 days from the filing of the tariff, the period subject to refund for improper classification shall begin on the date such investigation or hearing is initiated by the filing of a Commission motion or a complaint.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-502.5)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-502.5. Services alleged to be improperly classified.

(a) Any action or proceeding pending before the Commission upon the effective date of this amendatory Act of the 92nd General Assembly in which it is alleged that a telecommunications carrier has improperly classified services as competitive, other than a case pertaining to Section 13-506.1, shall be abated and shall not be maintained or continued.

(b) All retail telecommunications services provided to business end users by any telecommunications carrier subject, as of May 1, 2001, to alternative regulation under an alternative regulation plan pursuant to Section 13-506.1 of this Act shall be classified as competitive as of the effective date of this amendatory Act of the 92nd General Assembly without further Commission review. Rates for retail telecommunications services provided to business end users with 4 or fewer access lines shall not exceed the rates the carrier charged for those services on May 1, 2001. This restriction upon the rates of retail telecommunications services provided to business end users shall remain in force and effect through July 1, 2005; provided, however, that nothing in this Section shall be construed to prohibit reduction of those rates. Rates for retail telecommunications services provided to business end users with 5 or more access lines shall not be subject to the restrictions set forth in this subsection.

(c) All retail vertical services, as defined herein, that are provided by a telecommunications carrier subject, as of May 1, 2001, to alternative regulation under an alternative regulation plan pursuant to Section 13-506.1 of this Act shall be classified as competitive as of June 1, 2003 without further Commission review. Retail vertical services shall include, for purposes of this Section, services available on a subscriber's telephone line that the subscriber pays for on a periodic or per use basis, but shall not include caller identification and call waiting.

(d) Any action or proceeding before the Commission upon the effective date of this amendatory Act of the 92nd General Assembly, in which it is alleged that a telecommunications carrier has improperly classified services as competitive, other than a case pertaining to Section 13-506.1, shall be abated and the services the classification of which is at issue shall be deemed either competitive or noncompetitive as set forth in this Section. Any telecommunications carrier subject to an action or proceeding in which it is alleged that the telecommunications carrier has improperly classified services as competitive shall be deemed liable to refund, and shall refund, the sum of $90,000,000 to that class or those classes of its customers that were alleged to have paid rates in excess of noncompetitive rates as the result of the alleged improper classification. The telecommunications carrier shall make the refund no later than 120 days after the effective date of this amendatory Act of the 92nd General Assembly.

(e) Any telecommunications carrier subject to an action or proceeding in which it is alleged that the telecommunications carrier has improperly classified services as competitive shall also pay the sum of $15,000,000 to the Digital Divide Elimination Fund established pursuant to Section 5-20 of the Eliminate the Digital Divide Law, and shall further pay the sum of $15,000,000 to the Digital Divide Elimination Infrastructure Fund established pursuant to Section 13-301.3 of this Act. The telecommunications carrier shall make each of these payments in 3 installments of $5,000,000, payable on July 1 of 2002, 2003, and 2004. The telecommunications carrier shall have no further accounting for these payments, which shall be used for the purposes established in the Eliminate the Digital Divide Law.

(f) All other services shall be classified pursuant to Section 13-502 of this Act.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-503) (from Ch. 111 2/3, par. 13-503)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-503. Information available to the public. With respect to rates or other charges made, demanded, or received for any telecommunications service offered, provided, or to be provided, that is subject to subsection (a) of Section 13-501 of this Act, telecommunications carriers shall comply with the publication and filing provisions of Sections 9-101, 9-102, 9-102.1, and 9-201 of this Act. Except for the provision of services offered or provided by payphone providers pursuant to a tariff, telecommunications carriers shall make all tariffs and all written service offerings for competitive telecommunications service available electronically to the public without requiring a password or other means of registration. A telecommunications carrier's website shall, if applicable, provide in a conspicuous manner information on the rates, charges, terms, and conditions of service available and a toll-free telephone number that may be used to contact an agent for assistance with obtaining rate or other charge information or the terms and conditions of service.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-504) (from Ch. 111 2/3, par. 13-504)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-504. Application of ratemaking provisions of Article IX.

(a) Except where the context clearly renders such provisions inapplicable, the ratemaking provisions of Article IX of this Act relating to public utilities are fully and equally applicable to the rates, charges, tariffs and classifications for the offer or provision of noncompetitive telecommunications services. However, the ratemaking provisions do not apply to any proposed change in rates or charges, any proposed change in any classification or tariff resulting in a change in rates or charges, or the establishment of new services and rates therefor for a noncompetitive local exchange telecommunications service offered or provided by a local exchange telecommunications carrier with no more than 35,000 subscriber access lines. Proposed changes in rates, charges, classifications, or tariffs meeting these criteria shall be permitted upon the filing of the proposed tariff and 30 days notice to the Commission and all potentially affected customers. The proposed changes shall not be subject to suspension. The Commission shall investigate whether any proposed change is just and reasonable only if a telecommunications carrier that is a customer of the local exchange telecommunications carrier or 10% of the potentially affected access line subscribers of the local exchange telecommunications carrier shall file a petition or complaint requesting an investigation of the proposed changes. When the telecommunications carrier or 10% of the potentially affected access line subscribers of a local exchange telecommunications carrier file a complaint, the Commission shall, after notice and hearing, have the power and duty to establish the rates, charges, classifications, or tariffs it finds to be just and reasonable.

(b) Subsection (c) of Section 13-502 and Sections 13-505.1, 13-505.4, 13-505.6, and 13-507 of this Article do not apply to rates or charges or proposed changes in rates or charges for applicable competitive or interexchange services when offered or provided by a local exchange telecommunications carrier with no more than 35,000 subscriber access lines. In addition, Sections 13-514, 13-515, and 13-516 do not apply to telecommunications carriers with no more than 35,000 subscriber access lines. The Commission may require telecommunications carriers with no more than 35,000 subscriber access lines to furnish information that the Commission deems necessary for a determination that rates and charges for any competitive telecommunications service are just and reasonable.

(c) For a local exchange telecommunications carrier with no more than 35,000 access lines, the Commission shall consider and adjust, as appropriate, a local exchange telecommunications carrier's depreciation rates only in ratemaking proceedings.

(d) Article VI and Sections 7-101 and 7-102 of Article VII of this Act pertaining to public utilities, public utility rates and services, and the regulation thereof are not applicable to local exchange telecommunication carriers with no more than 35,000 subscriber access lines.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-505) (from Ch. 111 2/3, par. 13-505)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-505. Rate changes; competitive services. Any proposed increase or decrease in rates or charges, or proposed change in any classification, written service offering, or tariff resulting in an increase or decrease in rates or charges, for a competitive telecommunications service shall be permitted upon the filing with the Commission or posting on the telecommunications carrier's website of the proposed rate, charge, classification, written service offering, or tariff pursuant to Section 13-501 of this Act. Notice of an increase shall be given, no later than the prior billing cycle, to all potentially affected customers by mail or equivalent means of notice, including electronic if the customer has elected electronic billing. Additional notice by publication in a newspaper of general circulation may also be given.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-505.1)

Sec. 13-505.1. (Repealed).

(Source: P.A. 87-856. Repealed by P.A. 96-927, eff. 6-15-10.)

(220 ILCS 5/13-505.2) (from Ch. 111 2/3, par. 13-505.2)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-505.2. Nondiscrimination in the provision of noncompetitive services. A telecommunications carrier that offers both noncompetitive and competitive services shall offer the noncompetitive services under the same rates, terms, and conditions without unreasonable discrimination to all persons, including all telecommunications carriers and competitors. A telecommunications carrier that offers a noncompetitive service together with any optional feature or functionality shall offer the noncompetitive service together with each optional feature or functionality under the same rates, terms, and conditions without unreasonable discrimination to all persons, including all telecommunications carriers and competitors.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-505.3) (from Ch. 111 2/3, par. 13-505.3)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-505.3. Services for resale. A telecommunications carrier that offers both noncompetitive and competitive services shall offer all noncompetitive services, together with each applicable optional feature or functionality, subject to resale; however, the Commission may determine under Article IX of this Act that certain noncompetitive services, together with each applicable optional feature or functionality, that are offered to residence customers under different rates, charges, terms, or conditions than to other customers should not be subject to resale under the rates, charges, terms, or conditions available only to residence customers.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-505.4) (from Ch. 111 2/3, par. 13-505.4)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-505.4. Provision of noncompetitive services.

(a) A telecommunications carrier that offers or provides a noncompetitive service, service element, feature, or functionality on a separate, stand-alone basis to any customer shall provide that service, service element, feature, or functionality pursuant to tariff to all persons, including all telecommunications carriers and competitors, in accordance with the provisions of this Article.

(b) A telecommunications carrier that offers or provides a noncompetitive service, service element, feature, or functionality to any customer as part of an offering of competitive services pursuant to tariff or contract shall publicly disclose the offering or provisioning of the noncompetitive service, service element, feature, or functionality by filing with the Commission information that generally describes the offering or provisioning and that shows the rates, terms, and conditions of the noncompetitive service, service element, feature, or functionality. The information shall be filed with the Commission concurrently with the filing of the tariff or not more than 10 days following the customer's acceptance of the offering in a contract.

(c) A telecommunications carrier that is not subject to regulation under an alternative regulation plan pursuant to Section 13-506.1 of this Act may reduce the rate or charge for a noncompetitive service, service element, feature, or functionality offered to customers on a separate, stand-alone basis or as part of a bundled service offering by filing with the Commission a tariff that shows the reduced rate or charge and all applicable terms and conditions of the noncompetitive service, service element, feature, or functionality or bundled offering. The reduction of rates or charges shall be permitted upon the filing of the proposed rate, charge, classification, tariff, or bundled offering. The total price of a bundled offering shall not attribute any portion of the charge to services subject to the jurisdiction of the Commission and shall not be binding on the Commission in any proceeding under Article IX of this Act to set the revenue requirement or to set just and reasonable rates for services subject to the jurisdiction of the Commission. Prices for bundles shall not be subject to Section 13-505.1 of this Act. For purposes of this subsection (c), a bundle is a group of services offered together for a fixed price where at least one of the services is an interLATA service as that term is defined in 47 U.S.C. 153(21), a cable service or a video service, a community antenna television service, a satellite broadcast service, a public mobile service as defined in Section 13-214 of this Act, or an advanced telecommunications service as "advanced telecommunications services" is defined in Section 13-517 of this Act.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-505.5) (from Ch. 111 2/3, par. 13-505.5)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-505.5. Requests for new noncompetitive services. Any party may petition the Commission to request the provision of a noncompetitive service not currently provided by a local exchange carrier within its service territory. The Commission shall grant the petition, provided that it can be demonstrated that the provisioning of the requested service is technically and economically practicable considering demand for the service, and absent a finding that provision of the service is otherwise contrary to the public interest. The Commission shall render its decision within 180 days after the filing of the petition unless extension of the time period is agreed to by all the parties to the proceeding.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-505.6) (from Ch. 111 2/3, par. 13-505.6)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-505.6. Unbundling of noncompetitive services. A telecommunications carrier that provides both noncompetitive and competitive telecommunications services shall provide all noncompetitive telecommunications services on an unbundled basis to the same extent the Federal Communications Commission requires that carrier to unbundle the same services provided under its jurisdiction. The Illinois Commerce Commission may require additional unbundling of noncompetitive telecommunications services over which it has jurisdiction based on a determination, after notice and hearing, that additional unbundling is in the public interest and is consistent with the policy goals and other provisions of this Act.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-505.7)

Sec. 13-505.7. (Repealed).

(Source: P.A. 90-655, eff. 7-30-98. Repealed by P.A. 96-927, eff. 6-15-10.)

(220 ILCS 5/13-505.8)

Sec. 13-505.8. (Repealed).

(Source: P.A. 90-185, eff. 7-23-97. Renumbered by P.A. 90-655. Repealed by P.A. 90-574, eff. 3-20-98.)

(220 ILCS 5/13-506)

Sec. 13-506. (Repealed).

(Source: P.A. 90-655, eff. 7-30-98. Repealed by P.A. 96-927, eff. 6-15-10.)

(220 ILCS 5/13-506.1) (from Ch. 111 2/3, par. 13-506.1)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-506.1. Alternative forms of regulation for noncompetitive services.

(a) Notwithstanding any of the ratemaking provisions of this Article or Article IX that are deemed to require rate of return regulation, the Commission may implement alternative forms of regulation in order to establish just and reasonable rates for noncompetitive telecommunications services including, but not limited to, price regulation, earnings sharing, rate moratoria, or a network modernization plan. The Commission is authorized to adopt different forms of regulation to fit the particular characteristics of different telecommunications carriers and their service areas.

In addition to the public policy goals declared in Section 13-103, the Commission shall consider, in determining the appropriateness of any alternative form of regulation, whether it will:

(1) reduce regulatory delay and costs over time;

(2) encourage innovation in services;

(3) promote efficiency;

(4) facilitate the broad dissemination of technical improvements to all classes of ratepayers;

(5) enhance economic development of the State; and

(6) provide for fair, just, and reasonable rates.

(b) A telecommunications carrier providing noncompetitive telecommunications services may petition the Commission to regulate the rates or charges of its noncompetitive services under an alternative form of regulation. The telecommunications carrier shall submit with its petition its plan for an alternative form of regulation. The Commission shall review and may modify or reject the carrier's proposed plan. The Commission also may initiate consideration of alternative forms of regulation for a telecommunications carrier on its own motion. The Commission may approve the plan or modified plan and authorize its implementation only if it finds, after notice and hearing, that the plan or modified plan at a minimum:

(1) is in the public interest;

(2) will produce fair, just, and reasonable rates for telecommunications services;

(3) responds to changes in technology and the structure of the telecommunications industry that are, in fact, occurring;

(4) constitutes a more appropriate form of regulation based on the Commission's overall consideration of the policy goals set forth in Section 13-103 and this Section;

(5) specifically identifies how ratepayers will benefit from any efficiency gains, cost savings arising out of the regulatory change, and improvements in productivity due to technological change;

(6) will maintain the quality and availability of telecommunications services; and

(7) will not unduly or unreasonably prejudice or disadvantage any particular customer class, including telecommunications carriers.

(c) An alternative regulation plan approved under this Section shall provide, as a condition for Commission approval of the plan, that for the first 3 years the plan is in effect, basic residence service rates shall be no higher than those rates in effect 180 days before the filing of the plan. This provision shall not be used as a justification or rationale for an increase in basic service rates for any other customer class. For purposes of this Section, "basic residence service rates" shall mean monthly recurring charges for the telecommunications carrier's lowest priced primary residence network access lines, along with any associated untimed or flat rate local usage charges. Nothing in this subsection (c) shall preclude the Commission from approving an alternative regulation plan that results in rate reductions provided all the requirements of subsection (b) are satisfied by the plan.

(d) Any alternative form of regulation granted for a multi-year period under this Section shall provide for annual or more frequent reporting to the Commission to document that the requirements of the plan are being properly implemented.

(e) Upon petition by the telecommunications carrier or any other person or upon its own motion, the Commission may rescind its approval of an alternative form of regulation if, after notice and hearing, it finds that the conditions set forth in subsection (b) of this Section can no longer be satisfied. Any person may file a complaint alleging that the rates charged by a telecommunications carrier under an alternative form of regulation are unfair, unjust, unreasonable, unduly discriminatory, or are otherwise not consistent with the requirements of this Article; provided, that the complainant shall bear the burden of proving the allegations in the complaint.

(f) Nothing in this Section shall be construed to authorize the Commission to render Sections 9-241, 9-250, and 13-505.2 inapplicable to noncompetitive services.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-506.2)

(Text of Section before amendment by P.A. 103-826)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-506.2. Market regulation for competitive retail services.

(a) Definitions. As used in this Section:

(1) "Electing Provider" means a telecommunications carrier that is subject to either rate regulation pursuant to Section 13-504 or Section 13-505 or alternative regulation pursuant to Section 13-506.1 and that elects to have the rates, terms, and conditions of its competitive retail telecommunications services solely determined and regulated pursuant to the terms of this Article.

(2) "Basic local exchange service" means either a stand-alone residence network access line and per-call usage or, for any geographic area in which such stand-alone service is not offered, a stand-alone flat rate residence network access line for which local calls are not charged for frequency or duration. Extended Area Service shall be included in basic local exchange service.

(3) "Existing customer" means a residential customer who was subscribing to one of the optional packages described in subsection (d) of this Section as of the effective date of this amendatory Act of the 99th General Assembly. A customer who was subscribing to one of the optional packages on that date but stops subscribing thereafter shall not be considered an "existing customer" as of the date the customer stopped subscribing to the optional package, unless the stoppage is temporary and caused by the customer changing service address locations, or unless the customer resumes subscribing and is eligible to receive discounts on monthly telephone service under the federal Lifeline program, 47 C.F.R. Part 54, Subpart E.

(4) "New customer" means a residential customer who was not subscribing to one of the optional packages described in subsection (d) of this Section as of the effective date of this amendatory Act of the 99th General Assembly and who is eligible to receive discounts on monthly telephone service under the federal Lifeline program, 47 C.F.R. Part 54, Subpart E.

(b) Election for market regulation. Notwithstanding any other provision of this Act, an Electing Provider may elect to have the rates, terms, and conditions of its competitive retail telecommunications services solely determined and regulated pursuant to the terms of this Section by filing written notice of its election for market regulation with the Commission. The notice of election shall designate the geographic area of the Electing Provider's service territory where the market regulation shall apply, either on a state-wide basis or in one or more specified Market Service Areas ("MSA") or Exchange areas. An Electing Provider shall not make an election for market regulation under this Section unless it commits in its written notice of election for market regulation to fulfill the conditions and requirements in this Section in each geographic area in which market regulation is elected. Immediately upon filing the notice of election for market regulation, the Electing Provider shall be subject to the jurisdiction of the Commission to the extent expressly provided in this Section.

(c) Competitive classification. Market regulation shall be available for competitive retail telecommunications services as provided in this subsection.

(1) For geographic areas in which telecommunications services provided by the Electing Provider were classified as competitive either through legislative action or a tariff filing pursuant to Section 13-502 prior to January 1, 2010, and that are included in the Electing Provider's notice of election pursuant to subsection (b) of this Section, such services, and all recurring and nonrecurring charges associated with, related to or used in connection with such services, shall be classified as competitive without further Commission review. For services classified as competitive pursuant to this subsection, the requirements or conditions in any order or decision rendered by the Commission pursuant to Section 13-502 prior to the effective date of this amendatory Act of the 96th General Assembly, except for the commitments made by the Electing Provider in such order or decision concerning the optional packages required in subsection (d) of this Section and basic local exchange service as defined in this Section, shall no longer be in effect and no Commission investigation, review, or proceeding under Section 13-502 shall be continued, conducted, or maintained with respect to such services, charges, requirements, or conditions. If an Electing Provider has ceased providing optional packages to customers pursuant to subdivision (d)(8) of this Section, the commitments made by the Electing Provider in such order or decision concerning the optional packages under subsection (d) of this Section shall no longer be in effect and no Commission investigation, review, or proceeding under Section 13-502 shall be continued, conducted, or maintained with respect to such packages.

(2) For those geographic areas in which residential local exchange telecommunications services have not been classified as competitive as of the effective date of this amendatory Act of the 96th General Assembly, all telecommunications services provided to residential and business end users by an Electing Provider in the geographic area that is included in its notice of election pursuant to subsection (b) shall be classified as competitive for purposes of this Article without further Commission review.

(3) If an Electing Provider was previously subject to alternative regulation pursuant to Section 13-506.1 of this Article, the alternative regulation plan shall terminate in whole for all services subject to that plan and be of no force or effect, without further Commission review or action, when the Electing Provider's residential local exchange telecommunications service in each MSA in its telecommunications service area in the State has been classified as competitive pursuant to either subdivision (c)(1) or (c)(2) of this Section.

(4) The service packages described in Section 13-518 shall be classified as competitive for purposes of this Section if offered by an Electing Provider in a geographic area in which local exchange telecommunications service has been classified as competitive pursuant to either subdivision (c)(1) or (c)(2) of this Section.

(5) Where a service, or its functional equivalent, or a substitute service offered by a carrier that is not an Electing Provider or the incumbent local exchange carrier for that area is also being offered by an Electing Provider for some identifiable class or group of customers in an exchange, group of exchanges, or some other clearly defined geographical area, the service offered by a carrier that is not an Electing Provider or the incumbent local exchange carrier for that area shall be classified as competitive without further Commission review.

(6) Notwithstanding any other provision of this Act, retail telecommunications services classified as competitive pursuant to Section 13-502 or subdivision (c)(5) of this Section shall have their rates, terms, and conditions solely determined and regulated pursuant to the terms of this Section in the same manner and to the same extent as the competitive retail telecommunications services of an Electing Provider, except that subsections (d), (g), and (j) of this Section shall not apply to a carrier that is not an Electing Provider or to the competitive telecommunications services of a carrier that is not an Electing Provider. The access services of a carrier that is not an Electing Provider shall remain subject to Section 13-900.2. The requirements in subdivision (e)(3) of this Section shall not apply to retail telecommunications services classified as competitive pursuant to Section 13-502 or subdivision (c)(5) of this Section, except that, upon request from the Commission, the telecommunications carrier providing competitive retail telecommunications services shall provide a report showing the number of credits and exemptions for the requested time period.

(d) Consumer choice safe harbor options.

(1) Subject to subdivision (d)(8) of this Section, an Electing Provider in each of the MSA or Exchange areas classified as competitive pursuant to subdivision (c)(1) or (c)(2) of this Section shall offer to all residential customers who choose to subscribe the following optional packages of services priced at the same rate levels in effect on January 1, 2010:

(A) A basic package, which shall consist of a stand-alone residential network access line and 30 local calls. If the Electing Provider offers a stand-alone residential access line and local usage on a per call basis, the price for the basic package shall be the Electing Provider's applicable price in effect on January 1, 2010 for the sum of a residential access line and 30 local calls, additional calls over 30 calls shall be provided at the current per call rate. However, this basic package is not required if stand-alone residential network access lines or per-call local usage are not offered by the Electing Provider in the geographic area on January 1, 2010 or if the Electing Provider has not increased its stand-alone network access line and local usage rates, including Extended Area Service rates, since January 1, 2010.

(B) An extra package, which shall consist of residential basic local exchange network access line and unlimited local calls. The price for the extra package shall be the Electing Provider's applicable price in effect on January 1, 2010 for a residential access line with unlimited local calls.

(C) A plus package, which shall consist of residential basic local exchange network access line, unlimited local calls, and the customer's choice of 2 vertical services offered by the Electing Provider. The term "vertical services" as used in this subsection, includes, but is not limited to, call waiting, call forwarding, 3-way calling, caller ID, call tracing, automatic callback, repeat dialing, and voicemail. The price for the plus package shall be the Electing Provider's applicable price in effect on January 1, 2010 for the sum of a residential access line with unlimited local calls and 2 times the average price for the vertical features included in the package.

(2) Subject to subdivision (d)(8) of this Section, for those geographic areas in which local exchange telecommunications services were classified as competitive on the effective date of this amendatory Act of the 96th General Assembly, an Electing Provider in each such MSA or Exchange area shall be subject to the same terms and conditions as provided in commitments made by the Electing Provider in connection with such previous competitive classifications, which shall apply with equal force under this Section, except as follows: (i) the limits on price increases on the optional packages required by this Section shall be extended consistent with subsection (d)(1) of this Section and (ii) the price for the extra package required by subsection (d)(1)(B) shall be reduced by one dollar from the price in effect on January 1, 2010. In addition, if an Electing Provider obtains a competitive classification pursuant to subsection (c)(1) and (c)(2), the price for the optional packages shall be determined in such area in compliance with subsection (d)(1), except the price for the plus package required by subsection (d)(1) (C) shall be the lower of the price for such area or the price of the plus package in effect on January 1, 2010 for areas classified as competitive pursuant to subsection (c)(1).

(3) To the extent that the requirements in Section 13-518 applied to a telecommunications carrier prior to the effective date of this Section and that telecommunications carrier becomes an Electing Provider in accordance with the provisions of this Section, the requirements in Section 13-518 shall cease to apply to that Electing Provider in those geographic areas included in the Electing Provider's notice of election pursuant to subsection (b) of this Section.

(4) Subject to subdivision (d)(8) of this Section, an Electing Provider shall make the optional packages required by this subsection and stand-alone residential network access lines and local usage, where offered, readily available to the public by providing information, in a clear manner, to residential customers. Information shall be made available on a website, and an Electing Provider shall provide notification to its customers every 6 months, provided that notification may consist of a bill page message that provides an objective description of the safe harbor options that includes a telephone number and website address where the customer may obtain additional information about the packages from the Electing Provider. The optional packages shall be offered on a monthly basis with no term of service requirement. An Electing Provider shall allow online electronic ordering of the optional packages and stand-alone residential network access lines and local usage, where offered, on its website in a manner similar to the online electronic ordering of its other residential services.

(5) Subject to subdivision (d)(8) of this Section, an Electing Provider shall comply with the Commission's existing rules, regulations, and notices in Title 83, Part 735 of the Illinois Administrative Code when offering or providing the optional packages required by this subsection (d) and stand-alone residential network access lines.

(6) Subject to subdivision (d)(8) of this Section, an Electing Provider shall provide to the Commission semi-annual subscribership reports as of June 30 and December 31 that contain the number of its customers subscribing to each of the consumer choice safe harbor packages required by subsection (d)(1) of this Section and the number of its customers subscribing to retail residential basic local exchange service as defined in subsection (a)(2) of this Section. The first semi-annual reports shall be made on April 1, 2011 for December 31, 2010, and on September 1, 2011 for June 30, 2011, and semi-annually on April 1 and September 1 thereafter. Such subscribership information shall be accorded confidential and proprietary treatment upon request by the Electing Provider.

(7) The Commission shall have the power, after notice and hearing as provided in this Article, upon complaint or upon its own motion, to take corrective action if the requirements of this Section are not complied with by an Electing Provider.

(8) On and after the effective date of this amendatory Act of the 99th General Assembly, an Electing Provider shall continue to offer and provide the optional packages described in this subsection (d) to existing customers and new customers. On and after July 1, 2017, an Electing Provider may immediately stop offering the optional packages described in this subsection (d) and, upon providing two notices to affected customers and to the Commission, may stop providing the optional packages described in this subsection (d) to all customers who subscribe to one of the optional packages. The first notice shall be provided at least 90 days before the date upon which the Electing Provider intends to stop providing the optional packages, and the second notice must be provided at least 30 days before that date. The first notice shall not be provided prior to July 1, 2017. Each notice must identify the date on which the Electing Provider intends to stop providing the optional packages, at least one alternative service available to the customer, and a telephone number by which the customer may contact a service representative of the Electing Provider. After July 1, 2017 with respect to new customers, and upon the expiration of the second notice period with respect to customers who were subscribing to one of the optional packages, subdivisions (d)(1), (d)(2), (d)(4), (d)(5), (d)(6), and (d)(7) of this Section shall not apply to the Electing Provider. Notwithstanding any other provision of this Article, an Electing Provider that has ceased providing the optional packages under this subdivision (d)(8) is not subject to Section 13-301(1)(c) of this Act. Notwithstanding any other provision of this Act, and subject to subdivision (d)(7) of this Section, the Commission's authority over the discontinuance of the optional packages described in this subsection (d) by an Electing Provider shall be governed solely by this subsection (d)(8).

(e) Service quality and customer credits for basic local exchange service.

(1) An Electing Provider shall meet the following service quality standards in providing basic local exchange service, which for purposes of this subsection (e), includes both basic local exchange service and any consumer choice safe harbor options that may be required by subsection (d) of this Section.

(A) Install basic local exchange service within 5 business days after receipt of an order from the customer unless the customer requests an installation date that is beyond 5 business days after placing the order for basic service and to inform the customer of the Electing Provider's duty to install service within this timeframe. If installation of service is requested on or by a date more than 5 business days in the future, the Electing Provider shall install service by the date requested.

(B) Restore basic local exchange service for the customer within 30 hours after receiving notice that the customer is out of service.

(C) Keep all repair and installation appointments for basic local exchange service if a customer premises visit requires a customer to be present. The appointment window shall be either a specific time or, at a maximum, a 4-hour time block during evening, weekend, and normal business hours.

(D) Inform a customer when a repair or installation appointment requires the customer to be present.

(2) Customers shall be credited by the Electing Provider for violations of basic local exchange service quality standards described in subdivision (e)(1) of this Section. The credits shall be applied automatically on the statement issued to the customer for the next monthly billing cycle following the violation or following the discovery of the violation. The next monthly billing cycle following the violation or the discovery of the violation means the billing cycle immediately following the billing cycle in process at the time of the violation or discovery of the violation, provided the total time between the violation or discovery of the violation and the issuance of the credit shall not exceed 60 calendar days. The Electing Provider is responsible for providing the credits and the customer is under no obligation to request such credits. The following credits shall apply:

(A) If an Electing Provider fails to repair an out-of-service condition for basic local exchange service within 30 hours, the Electing Provider shall provide a credit to the customer. If the service disruption is for more than 30 hours, but not more than 48 hours, the credit must be equal to a pro-rata portion of the monthly recurring charges for all basic local exchange services disrupted. If the service disruption is for more than 48 hours, but not more than 72 hours, the credit must be equal to at least 33% of one month's recurring charges for all local services disrupted. If the service disruption is for more than 72 hours, but not more than 96 hours, the credit must be equal to at least 67% of one month's recurring charges for all basic local exchange services disrupted. If the service disruption is for more than 96 hours, but not more than 120 hours, the credit must be equal to one month's recurring charges for all basic local exchange services disrupted. For each day or portion thereof that the service disruption continues beyond the initial 120-hour period, the Electing Provider shall also provide an additional credit of $20 per calendar day.

(B) If an Electing Provider fails to install basic local exchange service as required under subdivision (e)(1) of this Section, the Electing Provider shall waive 50% of any installation charges, or in the absence of an installation charge or where installation is pursuant to the Link Up program, the Electing Provider shall provide a credit of $25. If an Electing Provider fails to install service within 10 business days after the service application is placed, or fails to install service within 5 business days after the customer's requested installation date, if the requested date was more than 5 business days after the date of the order, the Electing Provider shall waive 100% of the installation charge, or in the absence of an installation charge or where installation is provided pursuant to the Link Up program, the Electing Provider shall provide a credit of $50. For each day that the failure to install service continues beyond the initial 10 business days, or beyond 5 business days after the customer's requested installation date, if the requested date was more than 5 business days after the date of the order, the Electing Provider shall also provide an additional credit of $20 per calendar day until the basic local exchange service is installed.

(C) If an Electing Provider fails to keep a scheduled repair or installation appointment when a customer premises visit requires a customer to be present as required under subdivision (e)(1) of this Section, the Electing Provider shall credit the customer $25 per missed appointment. A credit required by this subdivision does not apply when the Electing Provider provides the customer notice of its inability to keep the appointment no later than 8:00 pm of the day prior to the scheduled date of the appointment.

(D) Credits required by this subsection do not apply if the violation of a service quality standard:

(i) occurs as a result of a negligent or willful act on the part of the customer;

(ii) occurs as a result of a malfunction of customer-owned telephone equipment or inside wiring;

(iii) occurs as a result of, or is extended by, an emergency situation as defined in 83 Ill. Adm. Code 732.10;

(iv) is extended by the Electing Provider's inability to gain access to the customer's premises due to the customer missing an appointment, provided that the violation is not further extended by the Electing Provider;

(v) occurs as a result of a customer request to change the scheduled appointment, provided that the violation is not further extended by the Electing Provider;

(vi) occurs as a result of an Electing Provider's right to refuse service to a customer as provided in Commission rules; or

(vii) occurs as a result of a lack of facilities where a customer requests service at a geographically remote location, where a customer requests service in a geographic area where the Electing Provider is not currently offering service, or where there are insufficient facilities to meet the customer's request for service, subject to an Electing Provider's obligation for reasonable facilities planning.

(3) Each Electing Provider shall provide to the Commission on a quarterly basis and in a form suitable for posting on the Commission's website in conformance with the rules adopted by the Commission and in effect on April 1, 2010, a public report that includes the following data for basic local exchange service quality of service:

(A) With regard to credits due in accordance with subdivision (e)(2)(A) as a result of out-of-service conditions lasting more than 30 hours:

(i) the total dollar amount of any customer credits paid;

(ii) the number of credits issued for repairs between 30 and 48 hours;

(iii) the number of credits issued for repairs between 49 and 72 hours;

(iv) the number of credits issued for repairs between 73 and 96 hours;

(v) the number of credits used for repairs between 97 and 120 hours;

(vi) the number of credits issued for repairs greater than 120 hours; and

(vii) the number of exemptions claimed for each of the categories identified in subdivision (e)(2)(D).

(B) With regard to credits due in accordance with subdivision (e)(2)(B) as a result of failure to install basic local exchange service:

(i) the total dollar amount of any customer credits paid;

(ii) the number of installations after 5 business days;

(iii) the number of installations after 10 business days;

(iv) the number of installations after 11 business days; and

(v) the number of exemptions claimed for each of the categories identified in subdivision (e)(2)(D).

(C) With regard to credits due in accordance with subdivision (e)(2)(C) as a result of missed appointments:

(i) the total dollar amount of any customer credits paid;

(ii) the number of any customers receiving credits; and

(iii) the number of exemptions claimed for each of the categories identified in subdivision (e)(2)(D).

(D) The Electing Provider's annual report required by this subsection shall also include, for informational reporting, the performance data described in subdivisions (e)(2)(A), (e)(2)(B), and (e)(2)(C), and trouble reports per 100 access lines calculated using the Commission's existing applicable rules and regulations for such measures, including the requirements for service standards established in this Section.

(4) It is the intent of the General Assembly that the service quality rules and customer credits in this subsection (e) of this Section and other enforcement mechanisms, including fines and penalties authorized by Section 13-305, shall apply on a nondiscriminatory basis to all Electing Providers. Accordingly, notwithstanding any provision of any service quality rules promulgated by the Commission, any alternative regulation plan adopted by the Commission, or any other order of the Commission, any Electing Provider that is subject to any other order of the Commission and that violates or fails to comply with the service quality standards promulgated pursuant to this subsection (e) or any other order of the Commission shall not be subject to any fines, penalties, customer credits, or enforcement mechanisms other than such fines or penalties or customer credits as may be imposed by the Commission in accordance with the provisions of this subsection (e) and Section 13-305, which are to be generally applicable to all Electing Providers. The amount of any fines or penalties imposed by the Commission for failure to comply with the requirements of this subsection (e) shall be an appropriate amount, taking into account, at a minimum, the Electing Provider's gross annual intrastate revenue; the frequency, duration, and recurrence of the violation; and the relative harm caused to the affected customers or other users of the network. In imposing fines and penalties, the Commission shall take into account compensation or credits paid by the Electing Provider to its customers pursuant to this subsection (e) in compensation for any violation found pursuant to this subsection (e), and in any event the fine or penalty shall not exceed an amount equal to the maximum amount of a civil penalty that may be imposed under Section 13-305.

(5) An Electing Provider in each of the MSA or Exchange areas classified as competitive pursuant to subsection (c) of this Section shall fulfill the requirements in subdivision (e)(3) of this Section for 3 years after its notice of election becomes effective. After such 3 years, the requirements in subdivision (e)(3) of this Section shall not apply to such Electing Provider, except that, upon request from the Commission, the Electing Provider shall provide a report showing the number of credits and exemptions for the requested time period.

(f) Commission jurisdiction over competitive retail telecommunications services. Except as otherwise expressly stated in this Section, the Commission shall thereafter have no jurisdiction or authority over any aspect of competitive retail telecommunications service of an Electing Provider in those geographic areas included in the Electing Provider's notice of election pursuant to subsection (b) of this Section or of a retail telecommunications service classified as competitive pursuant to Section 13-502 or subdivision (c)(5) of this Section, heretofore subject to the jurisdiction of the Commission, including but not limited to, any requirements of this Article related to the terms, conditions, rates, quality of service, availability, classification or any other aspect of any competitive retail telecommunications services. No telecommunications carrier shall commit any unfair or deceptive act or practice in connection with any aspect of the offering or provision of any competitive retail telecommunications service. Nothing in this Article shall limit or affect any provisions in the Consumer Fraud and Deceptive Business Practices Act with respect to any unfair or deceptive act or practice by a telecommunications carrier.

(g) Commission authority over access services upon election for market regulation.

(1) As part of its Notice of Election for Market Regulation, the Electing Provider shall reduce its intrastate switched access rates to rates no higher than its interstate switched access rates in 4 installments. The first reduction must be made 30 days after submission of its complete application for Notice of Election for Market Regulation, and the Electing Provider must reduce its intrastate switched access rates by an amount equal to 33% of the difference between its current intrastate switched access rates and its current interstate switched access rates. The second reduction must be made no later than one year after the first reduction, and the Electing Provider must reduce its then current intrastate switched access rates by an amount equal to 41% of the difference between its then current intrastate switched access rates and its then current interstate switched access rates. The third reduction must be made no later than one year after the second reduction, and the Electing Provider must reduce its then current intrastate switched access rates by an amount equal to 50% of the difference between its then current intrastate switched access rate and its then current interstate switched access rates. The fourth reduction must be made on or before June 30, 2013, and the Electing Provider must reduce its intrastate switched access rate to mirror its then current interstate switched access rates and rate structure. Following the fourth reduction, each Electing Provider must continue to set its intrastate switched access rates to mirror its interstate switched access rates and rate structure. For purposes of this subsection, the rate for intrastate switched access service means the composite, per-minute rate for that service, including all applicable fixed and traffic-sensitive charges, including, but not limited to, carrier common line charges.

(2) Nothing in paragraph (1) of this subsection (g) prohibits an Electing Provider from electing to offer intrastate switched access service at rates lower than its interstate switched access rates.

(3) The Commission shall have no authority to order an Electing Provider to set its rates for intrastate switched access at a level lower than its interstate switched access rates.

(4) The Commission's authority under this subsection (g) shall only apply to Electing Providers under Market Regulation. The Commission's authority over switched access services for all other carriers is retained under Section 13-900.2 of this Act.

(h) Safety of service equipment and facilities.

(1) An Electing Provider shall furnish, provide, and maintain such service instrumentalities, equipment, and facilities as shall promote the safety, health, comfort, and convenience of its patrons, employees, and public and as shall be in all respects adequate, reliable, and efficient without discrimination or delay. Every Electing Provider shall provide service and facilities that are in all respects environmentally safe.

(2) The Commission is authorized to conduct an investigation of any Electing Provider or part thereof. The investigation may examine the reasonableness, prudence, or efficiency of any aspect of the Electing Provider's operations or functions that may affect the adequacy, safety, efficiency, or reliability of telecommunications service. The Commission may conduct or order an investigation only when it has reasonable grounds to believe that the investigation is necessary to assure that the Electing Provider is providing adequate, efficient, reliable, and safe service. The Commission shall, before initiating any such investigation, issue an order describing the grounds for the investigation and the appropriate scope and nature of the investigation, which shall be reasonably related to the grounds relied upon by the Commission in its order.

(i) (Blank).

(j) Application of Article VII. The provisions of Sections 7-101, 7-102, 7-104, 7-204, 7-205, and 7-206 of this Act are applicable to an Electing Provider offering or providing retail telecommunications service, and the Commission's regulation thereof, except that (1) the approval of contracts and arrangements with affiliated interests required by paragraph (3) of Section 7-101 shall not apply to such telecommunications carriers provided that, except as provided in item (2), those contracts and arrangements shall be filed with the Commission; (2) affiliated interest contracts or arrangements entered into by such telecommunications carriers where the increased obligation thereunder does not exceed the lesser of $5,000,000 or 5% of such carrier's prior annual revenue from noncompetitive services are not required to be filed with the Commission; and (3) any consent and approval of the Commission required by Section 7-102 is not required for the sale, lease, assignment, or transfer by any Electing Provider of any property that is not necessary or useful in the performance of its duties to the public.

(k) Notwithstanding other provisions of this Section, the Commission retains its existing authority to enforce the provisions, conditions, and requirements of the following Sections of this Article: 13-101, 13-103, 13-201, 13-301, 13-301.1, 13-301.2, 13-301.3, 13-303, 13-303.5, 13-304, 13-305, 13-401, 13-401.1, 13-402, 13-403, 13-404, 13-404.1, 13-404.2, 13-405, 13-406, 13-501, 13-501.5, 13-503, 13-505, 13-509, 13-510, 13-512, 13-513, 13-514, 13-515, 13-516, 13-519, 13-702, 13-703, 13-704, 13-705, 13-706, 13-707, 13-709, 13-713, 13-801, 13-802.1, 13-804, 13-900, 13-900.1, 13-900.2, 13-901, 13-902, and 13-903, which are fully and equally applicable to Electing Providers and to telecommunications carriers providing retail telecommunications service classified as competitive pursuant to Section 13-502 or subdivision (c)(5) of this Section subject to the provisions of this Section. On the effective date of this amendatory Act of the 98th General Assembly, the following Sections of this Article shall cease to apply to Electing Providers and to telecommunications carriers providing retail telecommunications service classified as competitive pursuant to Section 13-502 or subdivision (c)(5) of this Section: 13-302, 13-405.1, 13-502, 13-502.5, 13-504, 13-505.2, 13-505.3, 13-505.4, 13-505.5, 13-505.6, 13-506.1, 13-507, 13-507.1, 13-508, 13-508.1, 13-517, 13-518, 13-601, 13-701, and 13-712.

(Source: P.A. 99-6, eff. 6-29-15; 100-20, eff. 7-1-17; 100-840, eff. 8-13-18.)

(Text of Section after amendment by P.A. 103-826)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-506.2. Market regulation for competitive retail services.

(a) Definitions. As used in this Section:

(1) "Electing Provider" means a telecommunications carrier that is subject to either rate regulation pursuant to Section 13-504 or Section 13-505 or alternative regulation pursuant to Section 13-506.1 and that elects to have the rates, terms, and conditions of its competitive retail telecommunications services solely determined and regulated pursuant to the terms of this Article.

(2) "Basic local exchange service" means either a stand-alone residence network access line and per-call usage or, for any geographic area in which such stand-alone service is not offered, a stand-alone flat rate residence network access line for which local calls are not charged for frequency or duration. Extended Area Service shall be included in basic local exchange service.

(3) "Existing customer" means a residential customer who was subscribing to one of the optional packages described in subsection (d) of this Section as of the effective date of this amendatory Act of the 99th General Assembly. A customer who was subscribing to one of the optional packages on that date but stops subscribing thereafter shall not be considered an "existing customer" as of the date the customer stopped subscribing to the optional package, unless the stoppage is temporary and caused by the customer changing service address locations, or unless the customer resumes subscribing and is eligible to receive discounts on monthly telephone service under the federal Lifeline program, 47 C.F.R. Part 54, Subpart E.

(4) "New customer" means a residential customer who was not subscribing to one of the optional packages described in subsection (d) of this Section as of the effective date of this amendatory Act of the 99th General Assembly and who is eligible to receive discounts on monthly telephone service under the federal Lifeline program, 47 C.F.R. Part 54, Subpart E.

(b) Election for market regulation. Notwithstanding any other provision of this Act, an Electing Provider may elect to have the rates, terms, and conditions of its competitive retail telecommunications services solely determined and regulated pursuant to the terms of this Section by filing written notice of its election for market regulation with the Commission. The notice of election shall designate the geographic area of the Electing Provider's service territory where the market regulation shall apply, either on a state-wide basis or in one or more specified Market Service Areas ("MSA") or Exchange areas. An Electing Provider shall not make an election for market regulation under this Section unless it commits in its written notice of election for market regulation to fulfill the conditions and requirements in this Section in each geographic area in which market regulation is elected. Immediately upon filing the notice of election for market regulation, the Electing Provider shall be subject to the jurisdiction of the Commission to the extent expressly provided in this Section.

(c) Competitive classification. Market regulation shall be available for competitive retail telecommunications services as provided in this subsection.

(1) For geographic areas in which telecommunications services provided by the Electing Provider were classified as competitive either through legislative action or a tariff filing pursuant to Section 13-502 prior to January 1, 2010, and that are included in the Electing Provider's notice of election pursuant to subsection (b) of this Section, such services, and all recurring and nonrecurring charges associated with, related to or used in connection with such services, shall be classified as competitive without further Commission review. For services classified as competitive pursuant to this subsection, the requirements or conditions in any order or decision rendered by the Commission pursuant to Section 13-502 prior to the effective date of this amendatory Act of the 96th General Assembly, except for the commitments made by the Electing Provider in such order or decision concerning the optional packages required in subsection (d) of this Section and basic local exchange service as defined in this Section, shall no longer be in effect and no Commission investigation, review, or proceeding under Section 13-502 shall be continued, conducted, or maintained with respect to such services, charges, requirements, or conditions. If an Electing Provider has ceased providing optional packages to customers pursuant to subdivision (d)(8) of this Section, the commitments made by the Electing Provider in such order or decision concerning the optional packages under subsection (d) of this Section shall no longer be in effect and no Commission investigation, review, or proceeding under Section 13-502 shall be continued, conducted, or maintained with respect to such packages.

(2) For those geographic areas in which residential local exchange telecommunications services have not been classified as competitive as of the effective date of this amendatory Act of the 96th General Assembly, all telecommunications services provided to residential and business end users by an Electing Provider in the geographic area that is included in its notice of election pursuant to subsection (b) shall be classified as competitive for purposes of this Article without further Commission review.

(3) If an Electing Provider was previously subject to alternative regulation pursuant to Section 13-506.1 of this Article, the alternative regulation plan shall terminate in whole for all services subject to that plan and be of no force or effect, without further Commission review or action, when the Electing Provider's residential local exchange telecommunications service in each MSA in its telecommunications service area in the State has been classified as competitive pursuant to either subdivision (c)(1) or (c)(2) of this Section.

(4) The service packages described in Section 13-518 shall be classified as competitive for purposes of this Section if offered by an Electing Provider in a geographic area in which local exchange telecommunications service has been classified as competitive pursuant to either subdivision (c)(1) or (c)(2) of this Section.

(5) Where a service, or its functional equivalent, or a substitute service offered by a carrier that is not an Electing Provider or the incumbent local exchange carrier for that area is also being offered by an Electing Provider for some identifiable class or group of customers in an exchange, group of exchanges, or some other clearly defined geographical area, the service offered by a carrier that is not an Electing Provider or the incumbent local exchange carrier for that area shall be classified as competitive without further Commission review.

(6) Notwithstanding any other provision of this Act, retail telecommunications services classified as competitive pursuant to Section 13-502 or subdivision (c)(5) of this Section shall have their rates, terms, and conditions solely determined and regulated pursuant to the terms of this Section in the same manner and to the same extent as the competitive retail telecommunications services of an Electing Provider, except that subsections (d), (g), and (j) of this Section shall not apply to a carrier that is not an Electing Provider or to the competitive telecommunications services of a carrier that is not an Electing Provider. The access services of a carrier that is not an Electing Provider shall remain subject to Section 13-900.2. The requirements in subdivision (e)(3) of this Section shall not apply to retail telecommunications services classified as competitive pursuant to Section 13-502 or subdivision (c)(5) of this Section, except that, upon request from the Commission, the telecommunications carrier providing competitive retail telecommunications services shall provide a report showing the number of credits and exemptions for the requested time period.

(d) Consumer choice safe harbor options.

(1) Subject to subdivision (d)(8) of this Section, an Electing Provider in each of the MSA or Exchange areas classified as competitive pursuant to subdivision (c)(1) or (c)(2) of this Section shall offer to all residential customers who choose to subscribe the following optional packages of services priced at the same rate levels in effect on January 1, 2010:

(A) A basic package, which shall consist of a stand-alone residential network access line and 30 local calls. If the Electing Provider offers a stand-alone residential access line and local usage on a per call basis, the price for the basic package shall be the Electing Provider's applicable price in effect on January 1, 2010 for the sum of a residential access line and 30 local calls, additional calls over 30 calls shall be provided at the current per call rate. However, this basic package is not required if stand-alone residential network access lines or per-call local usage are not offered by the Electing Provider in the geographic area on January 1, 2010 or if the Electing Provider has not increased its stand-alone network access line and local usage rates, including Extended Area Service rates, since January 1, 2010.

(B) An extra package, which shall consist of residential basic local exchange network access line and unlimited local calls. The price for the extra package shall be the Electing Provider's applicable price in effect on January 1, 2010 for a residential access line with unlimited local calls.

(C) A plus package, which shall consist of residential basic local exchange network access line, unlimited local calls, and the customer's choice of 2 vertical services offered by the Electing Provider. The term "vertical services" as used in this subsection, includes, but is not limited to, call waiting, call forwarding, 3-way calling, caller ID, call tracing, automatic callback, repeat dialing, and voicemail. The price for the plus package shall be the Electing Provider's applicable price in effect on January 1, 2010 for the sum of a residential access line with unlimited local calls and 2 times the average price for the vertical features included in the package.

(2) Subject to subdivision (d)(8) of this Section, for those geographic areas in which local exchange telecommunications services were classified as competitive on the effective date of this amendatory Act of the 96th General Assembly, an Electing Provider in each such MSA or Exchange area shall be subject to the same terms and conditions as provided in commitments made by the Electing Provider in connection with such previous competitive classifications, which shall apply with equal force under this Section, except as follows: (i) the limits on price increases on the optional packages required by this Section shall be extended consistent with subsection (d)(1) of this Section and (ii) the price for the extra package required by subsection (d)(1)(B) shall be reduced by one dollar from the price in effect on January 1, 2010. In addition, if an Electing Provider obtains a competitive classification pursuant to subsection (c)(1) and (c)(2), the price for the optional packages shall be determined in such area in compliance with subsection (d)(1), except the price for the plus package required by subsection (d)(1) (C) shall be the lower of the price for such area or the price of the plus package in effect on January 1, 2010 for areas classified as competitive pursuant to subsection (c)(1).

(3) To the extent that the requirements in Section 13-518 applied to a telecommunications carrier prior to the effective date of this Section and that telecommunications carrier becomes an Electing Provider in accordance with the provisions of this Section, the requirements in Section 13-518 shall cease to apply to that Electing Provider in those geographic areas included in the Electing Provider's notice of election pursuant to subsection (b) of this Section.

(4) Subject to subdivision (d)(8) of this Section, an Electing Provider shall make the optional packages required by this subsection and stand-alone residential network access lines and local usage, where offered, readily available to the public by providing information, in a clear manner, to residential customers. Information shall be made available on a website, and an Electing Provider shall provide notification to its customers every 6 months, provided that notification may consist of a bill page message that provides an objective description of the safe harbor options that includes a telephone number and website address where the customer may obtain additional information about the packages from the Electing Provider. The optional packages shall be offered on a monthly basis with no term of service requirement. An Electing Provider shall allow online electronic ordering of the optional packages and stand-alone residential network access lines and local usage, where offered, on its website in a manner similar to the online electronic ordering of its other residential services.

(5) Subject to subdivision (d)(8) of this Section, an Electing Provider shall comply with the Commission's existing rules, regulations, and notices in Title 83, Part 735 of the Illinois Administrative Code when offering or providing the optional packages required by this subsection (d) and stand-alone residential network access lines.

(6) Subject to subdivision (d)(8) of this Section, an Electing Provider shall provide to the Commission semi-annual subscribership reports as of June 30 and December 31 that contain the number of its customers subscribing to each of the consumer choice safe harbor packages required by subsection (d)(1) of this Section and the number of its customers subscribing to retail residential basic local exchange service as defined in subsection (a)(2) of this Section. The first semi-annual reports shall be made on April 1, 2011 for December 31, 2010, and on September 1, 2011 for June 30, 2011, and semi-annually on April 1 and September 1 thereafter. Such subscribership information shall be accorded confidential and proprietary treatment upon request by the Electing Provider.

(7) The Commission shall have the power, after notice and hearing as provided in this Article, upon complaint or upon its own motion, to take corrective action if the requirements of this Section are not complied with by an Electing Provider.

(8) On and after the effective date of this amendatory Act of the 99th General Assembly, an Electing Provider shall continue to offer and provide the optional packages described in this subsection (d) to existing customers and new customers. On and after July 1, 2017, an Electing Provider may immediately stop offering the optional packages described in this subsection (d) and, upon providing two notices to affected customers and to the Commission, may stop providing the optional packages described in this subsection (d) to all customers who subscribe to one of the optional packages. The first notice shall be provided at least 90 days before the date upon which the Electing Provider intends to stop providing the optional packages, and the second notice must be provided at least 30 days before that date. The first notice shall not be provided prior to July 1, 2017. Each notice must identify the date on which the Electing Provider intends to stop providing the optional packages, at least one alternative service available to the customer, and a telephone number by which the customer may contact a service representative of the Electing Provider. After July 1, 2017 with respect to new customers, and upon the expiration of the second notice period with respect to customers who were subscribing to one of the optional packages, subdivisions (d)(1), (d)(2), (d)(4), (d)(5), (d)(6), and (d)(7) of this Section shall not apply to the Electing Provider. Notwithstanding any other provision of this Article, an Electing Provider that has ceased providing the optional packages under this subdivision (d)(8) is not subject to Section 13-301(1)(c) of this Act. Notwithstanding any other provision of this Act, and subject to subdivision (d)(7) of this Section, the Commission's authority over the discontinuance of the optional packages described in this subsection (d) by an Electing Provider shall be governed solely by this subsection (d)(8).

(e) Service quality and customer credits for basic local exchange service.

(1) An Electing Provider shall meet the following service quality standards in providing basic local exchange service, which for purposes of this subsection (e), includes both basic local exchange service and any consumer choice safe harbor options that may be required by subsection (d) of this Section.

(A) Install basic local exchange service within 5 business days after receipt of an order from the customer unless the customer requests an installation date that is beyond 5 business days after placing the order for basic service and to inform the customer of the Electing Provider's duty to install service within this timeframe. If installation of service is requested on or by a date more than 5 business days in the future, the Electing Provider shall install service by the date requested.

(B) Restore basic local exchange service for the customer within 30 hours after receiving notice that the customer is out of service.

(C) Keep all repair and installation appointments for basic local exchange service if a customer premises visit requires a customer to be present. The appointment window shall be either a specific time or, at a maximum, a 4-hour time block during evening, weekend, and normal business hours.

(D) Inform a customer when a repair or installation appointment requires the customer to be present.

(2) Customers shall be credited by the Electing Provider for violations of basic local exchange service quality standards described in subdivision (e)(1) of this Section. The credits shall be applied automatically on the statement issued to the customer for the next monthly billing cycle following the violation or following the discovery of the violation. The next monthly billing cycle following the violation or the discovery of the violation means the billing cycle immediately following the billing cycle in process at the time of the violation or discovery of the violation, provided the total time between the violation or discovery of the violation and the issuance of the credit shall not exceed 60 calendar days. The Electing Provider is responsible for providing the credits and the customer is under no obligation to request such credits. The following credits shall apply:

(A) If an Electing Provider fails to repair an out-of-service condition for basic local exchange service within 30 hours, the Electing Provider shall provide a credit to the customer. If the service disruption is for more than 30 hours, but not more than 48 hours, the credit must be equal to a pro-rata portion of the monthly recurring charges for all basic local exchange services disrupted. If the service disruption is for more than 48 hours, but not more than 72 hours, the credit must be equal to at least 33% of one month's recurring charges for all local services disrupted. If the service disruption is for more than 72 hours, but not more than 96 hours, the credit must be equal to at least 67% of one month's recurring charges for all basic local exchange services disrupted. If the service disruption is for more than 96 hours, but not more than 120 hours, the credit must be equal to one month's recurring charges for all basic local exchange services disrupted. For each day or portion thereof that the service disruption continues beyond the initial 120-hour period, the Electing Provider shall also provide an additional credit of $20 per calendar day.

(B) If an Electing Provider fails to install basic local exchange service as required under subdivision (e)(1) of this Section, the Electing Provider shall waive 50% of any installation charges, or in the absence of an installation charge or where installation is pursuant to the Link Up program, the Electing Provider shall provide a credit of $25. If an Electing Provider fails to install service within 10 business days after the service application is placed, or fails to install service within 5 business days after the customer's requested installation date, if the requested date was more than 5 business days after the date of the order, the Electing Provider shall waive 100% of the installation charge, or in the absence of an installation charge or where installation is provided pursuant to the Link Up program, the Electing Provider shall provide a credit of $50. For each day that the failure to install service continues beyond the initial 10 business days, or beyond 5 business days after the customer's requested installation date, if the requested date was more than 5 business days after the date of the order, the Electing Provider shall also provide an additional credit of $20 per calendar day until the basic local exchange service is installed.

(C) If an Electing Provider fails to keep a scheduled repair or installation appointment when a customer premises visit requires a customer to be present as required under subdivision (e)(1) of this Section, the Electing Provider shall credit the customer $25 per missed appointment. A credit required by this subdivision does not apply when the Electing Provider provides the customer notice of its inability to keep the appointment no later than 8:00 pm of the day prior to the scheduled date of the appointment.

(D) Credits required by this subsection do not apply if the violation of a service quality standard:

(i) occurs as a result of a negligent or willful act on the part of the customer;

(ii) occurs as a result of a malfunction of customer-owned telephone equipment or inside wiring;

(iii) occurs as a result of, or is extended by, an emergency situation as defined in 83 Ill. Adm. Code 732.10;

(iv) is extended by the Electing Provider's inability to gain access to the customer's premises due to the customer missing an appointment, provided that the violation is not further extended by the Electing Provider;

(v) occurs as a result of a customer request to change the scheduled appointment, provided that the violation is not further extended by the Electing Provider;

(vi) occurs as a result of an Electing Provider's right to refuse service to a customer as provided in Commission rules; or

(vii) occurs as a result of a lack of facilities where a customer requests service at a geographically remote location, where a customer requests service in a geographic area where the Electing Provider is not currently offering service, or where there are insufficient facilities to meet the customer's request for service, subject to an Electing Provider's obligation for reasonable facilities planning.

(3) Each Electing Provider shall provide to the Commission on a quarterly basis and in a form suitable for posting on the Commission's website in conformance with the rules adopted by the Commission and in effect on April 1, 2010, a public report that includes the following data for basic local exchange service quality of service:

(A) With regard to credits due in accordance with subdivision (e)(2)(A) as a result of out-of-service conditions lasting more than 30 hours:

(i) the total dollar amount of any customer credits paid;

(ii) the number of credits issued for repairs between 30 and 48 hours;

(iii) the number of credits issued for repairs between 49 and 72 hours;

(iv) the number of credits issued for repairs between 73 and 96 hours;

(v) the number of credits used for repairs between 97 and 120 hours;

(vi) the number of credits issued for repairs greater than 120 hours; and

(vii) the number of exemptions claimed for each of the categories identified in subdivision (e)(2)(D).

(B) With regard to credits due in accordance with subdivision (e)(2)(B) as a result of failure to install basic local exchange service:

(i) the total dollar amount of any customer credits paid;

(ii) the number of installations after 5 business days;

(iii) the number of installations after 10 business days;

(iv) the number of installations after 11 business days; and

(v) the number of exemptions claimed for each of the categories identified in subdivision (e)(2)(D).

(C) With regard to credits due in accordance with subdivision (e)(2)(C) as a result of missed appointments:

(i) the total dollar amount of any customer credits paid;

(ii) the number of any customers receiving credits; and

(iii) the number of exemptions claimed for each of the categories identified in subdivision (e)(2)(D).

(D) The Electing Provider's annual report required by this subsection shall also include, for informational reporting, the performance data described in subdivisions (e)(2)(A), (e)(2)(B), and (e)(2)(C), and trouble reports per 100 access lines calculated using the Commission's existing applicable rules and regulations for such measures, including the requirements for service standards established in this Section.

(4) It is the intent of the General Assembly that the service quality rules and customer credits in this subsection (e) of this Section and other enforcement mechanisms, including fines and penalties authorized by Section 13-305, shall apply on a nondiscriminatory basis to all Electing Providers. Accordingly, notwithstanding any provision of any service quality rules promulgated by the Commission, any alternative regulation plan adopted by the Commission, or any other order of the Commission, any Electing Provider that is subject to any other order of the Commission and that violates or fails to comply with the service quality standards promulgated pursuant to this subsection (e) or any other order of the Commission shall not be subject to any fines, penalties, customer credits, or enforcement mechanisms other than such fines or penalties or customer credits as may be imposed by the Commission in accordance with the provisions of this subsection (e) and Section 13-305, which are to be generally applicable to all Electing Providers. The amount of any fines or penalties imposed by the Commission for failure to comply with the requirements of this subsection (e) shall be an appropriate amount, taking into account, at a minimum, the Electing Provider's gross annual intrastate revenue; the frequency, duration, and recurrence of the violation; and the relative harm caused to the affected customers or other users of the network. In imposing fines and penalties, the Commission shall take into account compensation or credits paid by the Electing Provider to its customers pursuant to this subsection (e) in compensation for any violation found pursuant to this subsection (e), and in any event the fine or penalty shall not exceed an amount equal to the maximum amount of a civil penalty that may be imposed under Section 13-305.

(5) An Electing Provider in each of the MSA or Exchange areas classified as competitive pursuant to subsection (c) of this Section shall fulfill the requirements in subdivision (e)(3) of this Section for 3 years after its notice of election becomes effective. After such 3 years, the requirements in subdivision (e)(3) of this Section shall not apply to such Electing Provider, except that, upon request from the Commission, the Electing Provider shall provide a report showing the number of credits and exemptions for the requested time period.

(f) Commission jurisdiction over competitive retail telecommunications services. Except as otherwise expressly stated in this Section, the Commission shall thereafter have no jurisdiction or authority over any aspect of competitive retail telecommunications service of an Electing Provider in those geographic areas included in the Electing Provider's notice of election pursuant to subsection (b) of this Section or of a retail telecommunications service classified as competitive pursuant to Section 13-502 or subdivision (c)(5) of this Section, heretofore subject to the jurisdiction of the Commission, including but not limited to, any requirements of this Article related to the terms, conditions, rates, quality of service, availability, classification or any other aspect of any competitive retail telecommunications services. No telecommunications carrier shall commit any unfair or deceptive act or practice in connection with any aspect of the offering or provision of any competitive retail telecommunications service. Nothing in this Article shall limit or affect any provisions in the Consumer Fraud and Deceptive Business Practices Act with respect to any unfair or deceptive act or practice by a telecommunications carrier.

(g) Commission authority over access services upon election for market regulation.

(1) As part of its Notice of Election for Market Regulation, the Electing Provider shall reduce its intrastate switched access rates to rates no higher than its interstate switched access rates in 4 installments. The first reduction must be made 30 days after submission of its complete application for Notice of Election for Market Regulation, and the Electing Provider must reduce its intrastate switched access rates by an amount equal to 33% of the difference between its current intrastate switched access rates and its current interstate switched access rates. The second reduction must be made no later than one year after the first reduction, and the Electing Provider must reduce its then current intrastate switched access rates by an amount equal to 41% of the difference between its then current intrastate switched access rates and its then current interstate switched access rates. The third reduction must be made no later than one year after the second reduction, and the Electing Provider must reduce its then current intrastate switched access rates by an amount equal to 50% of the difference between its then current intrastate switched access rate and its then current interstate switched access rates. The fourth reduction must be made on or before June 30, 2013, and the Electing Provider must reduce its intrastate switched access rate to mirror its then current interstate switched access rates and rate structure. Following the fourth reduction, each Electing Provider must continue to set its intrastate switched access rates to mirror its interstate switched access rates and rate structure. For purposes of this subsection, the rate for intrastate switched access service means the composite, per-minute rate for that service, including all applicable fixed and traffic-sensitive charges, including, but not limited to, carrier common line charges.

(2) Nothing in paragraph (1) of this subsection (g) prohibits an Electing Provider from electing to offer intrastate switched access service at rates lower than its interstate switched access rates.

(3) The Commission shall have no authority to order an Electing Provider to set its rates for intrastate switched access at a level lower than its interstate switched access rates.

(4) The Commission's authority under this subsection (g) shall only apply to Electing Providers under Market Regulation. The Commission's authority over switched access services for all other carriers is retained under Section 13-900.2 of this Act.

(h) Safety of service equipment and facilities.

(1) An Electing Provider shall furnish, provide, and maintain such service instrumentalities, equipment, and facilities as shall promote the safety, health, comfort, and convenience of its patrons, employees, and public and as shall be in all respects adequate, reliable, and efficient without discrimination or delay. Every Electing Provider shall provide service and facilities that are in all respects environmentally safe.

(2) The Commission is authorized to conduct an investigation of any Electing Provider or part thereof. The investigation may examine the reasonableness, prudence, or efficiency of any aspect of the Electing Provider's operations or functions that may affect the adequacy, safety, efficiency, or reliability of telecommunications service. The Commission may conduct or order an investigation only when it has reasonable grounds to believe that the investigation is necessary to assure that the Electing Provider is providing adequate, efficient, reliable, and safe service. The Commission shall, before initiating any such investigation, issue an order describing the grounds for the investigation and the appropriate scope and nature of the investigation, which shall be reasonably related to the grounds relied upon by the Commission in its order.

(i) (Blank).

(j) Application of Article VII. The provisions of Sections 7-101, 7-102, 7-104, 7-204, 7-205, and 7-206 of this Act are applicable to an Electing Provider offering or providing retail telecommunications service, and the Commission's regulation thereof, except that (1) the approval of contracts and arrangements with affiliated interests required by paragraph (3) of Section 7-101 shall not apply to such telecommunications carriers provided that, except as provided in item (2), those contracts and arrangements shall be filed with the Commission; (2) affiliated interest contracts or arrangements entered into by such telecommunications carriers where the increased obligation thereunder does not exceed the lesser of $5,000,000 or 5% of such carrier's prior annual revenue from noncompetitive services are not required to be filed with the Commission; and (3) any consent and approval of the Commission required by Section 7-102 is not required for the sale, lease, assignment, or transfer by any Electing Provider of any property that is not necessary or useful in the performance of its duties to the public.

(k) Notwithstanding other provisions of this Section, the Commission retains its existing authority to enforce the provisions, conditions, and requirements of the following Sections of this Article: 13-101, 13-103, 13-201, 13-301, 13-301.2, 13-301.3, 13-303, 13-303.5, 13-304, 13-305, 13-401, 13-401.1, 13-402, 13-403, 13-404, 13-404.1, 13-404.2, 13-405, 13-406, 13-501, 13-501.5, 13-503, 13-505, 13-509, 13-510, 13-512, 13-513, 13-514, 13-515, 13-516, 13-519, 13-702, 13-703, 13-704, 13-705, 13-706, 13-707, 13-709, 13-713, 13-801, 13-802.1, 13-804, 13-900, 13-900.1, 13-900.2, 13-901, 13-902, and 13-903, which are fully and equally applicable to Electing Providers and to telecommunications carriers providing retail telecommunications service classified as competitive pursuant to Section 13-502 or subdivision (c)(5) of this Section subject to the provisions of this Section. On the effective date of this amendatory Act of the 98th General Assembly, the following Sections of this Article shall cease to apply to Electing Providers and to telecommunications carriers providing retail telecommunications service classified as competitive pursuant to Section 13-502 or subdivision (c)(5) of this Section: 13-302, 13-405.1, 13-502, 13-502.5, 13-504, 13-505.2, 13-505.3, 13-505.4, 13-505.5, 13-505.6, 13-506.1, 13-507, 13-507.1, 13-508, 13-508.1, 13-517, 13-518, 13-601, 13-701, and 13-712.

(Source: P.A. 103-826, eff. 1-1-25.)

(220 ILCS 5/13-507) (from Ch. 111 2/3, par. 13-507)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-507. In any proceeding permitting, approving, investigating, or establishing rates, charges, classifications, or tariffs for telecommunications services offered or provided by a telecommunications carrier that offers or provides both noncompetitive and competitive services, the Commission shall not allow any subsidy of competitive services or nonregulated activities by noncompetitive services. In the event that facilities are utilized or expenses are incurred for the provision of both competitive and noncompetitive services, the Commission shall apportion the facilities and expenses between noncompetitive services in the aggregate and competitive services in the aggregate and shall allow or establish rates or charges for the noncompetitive services which reflect only that portion of the facilities or expenses that it finds to be properly and reasonably apportioned to noncompetitive services. An apportionment of facilities or expenses between competitive and noncompetitive services, together with any corresponding rate changes, shall be made in general rate proceedings and in other proceedings, including service classification proceedings, that are necessary to ensure against any subsidy of competitive services by noncompetitive services. The Commission shall have the power to take or require such action as is necessary to ensure that rates or charges for noncompetitive services reflect only the value of facilities, or portion thereof, used and useful, and the expenses or portion thereof reasonably and prudently incurred, for the provision of the noncompetitive services. The Commission may, in such event, also establish, by rule, any additional procedures, rules, regulations, or mechanisms necessary to identify and properly account for the value or amount of such facilities or expenses.

The Commission may establish, by rule, appropriate methods for ensuring against cross-subsidization between competitive services and noncompetitive services as required under this Article, including appropriate methods for calculating the long-run service incremental costs of providing any telecommunications service and, when appropriate, group of services and methods for apportioning between noncompetitive services in the aggregate and competitive services in the aggregate the value of facilities utilized and expenses incurred to provide both competitive and noncompetitive services, for example, common overheads that are not accounted for in the long-run service incremental costs of individual services or groups of services. The Commission may order any telecommunications carrier to conduct a long-run service incremental cost study and to provide the results thereof to the Commission. Any cost study provided to the Commission pursuant to the provisions of this Section may, in the Commission's discretion, be accorded proprietary treatment. In addition to the requirements of subsection (c) of Section 13-502 and of Section 13-505.1 applicable to the rates and charges for individual competitive services, the aggregate gross revenues of all competitive services shall be equal to or greater than the sum of the long-run service incremental costs for all competitive services as a group and the value of other facilities and expenses apportioned to competitive services as a group under this Section.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-507.1)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-507.1. In any proceeding permitting, approving, investigating, or establishing rates, charges, classifications, or tariffs for telecommunications services classified as noncompetitive offered or provided by an incumbent local exchange carrier as that term is defined in Section 13-202.5 of this Act, the Commission shall not allow any subsidy of Internet services, cable services, or video services by the rates or charges for local exchange telecommunications services, including local services classified as noncompetitive.

(Source: P.A. 102-558, eff. 8-20-21.)

(220 ILCS 5/13-508) (from Ch. 111 2/3, par. 13-508)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-508. The Commission is authorized, after notice and hearing, to order a telecommunications carrier which offers or provides both competitive and noncompetitive telecommunications service to establish a fully separated subsidiary to provide all or part of such competitive service where:

(a) no less costly means is available and effective in fully and properly identifying and allocating costs between such carrier's competitive and noncompetitive telecommunications services; and

(b) the incremental cost of establishing and maintaining such subsidiary would not require increases in rates or charges to levels which would effectively preclude the offer or provision of the affected competitive telecommunications service.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-508.1) (from Ch. 111 2/3, par. 13-508.1)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-508.1. Separate subsidiary requirement for certain electronic publishing. A telecommunications carrier that offers or provides both competitive and noncompetitive services shall not provide (1) electronically published news, feature, or entertainment material of the type generally published in newspapers, or (2) electronic advertising services, except through a fully separated subsidiary; provided, however, that a telecommunications carrier shall be allowed to resell, without editing the content, news, feature, or entertainment material of the type generally published in newspapers that it purchases from an unaffiliated entity or from a separate subsidiary to the extent the separate subsidiary makes that material available to all other persons under the same rates, terms, and conditions. Nothing in this Section shall prohibit a telecommunications carrier from electronic advertising of its own regulated services or from providing tariffed telecommunications services to a separate subsidiary or an unaffiliated entity that provides electronically published news, feature, or entertainment material or electronic advertising services.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-509) (from Ch. 111 2/3, par. 13-509)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-509. Agreements for provisions of competitive telecommunications services differing from tariffs or written service offerings. A telecommunications carrier may negotiate with customers or prospective customers to provide competitive telecommunications service, and in so doing, may offer or agree to provide such service on such terms and for such rates or charges as are reasonable, without regard to any tariffs it may have filed with the Commission or written service offerings posted on the telecommunications carrier's website pursuant to Section 13-501(c) of this Act with respect to such services. Upon request of the Commission, the telecommunications carrier shall submit to the Commission written notice of a list of any such agreements (which list may be filed electronically) within the past year. The notice shall identify the general nature of all such agreements. A copy of each such agreement shall be provided to the Commission within 10 business days after a request for review of the agreement is made by the Commission or is made to the Commission by another telecommunications carrier or by a party to such agreement.

Any agreement or notice entered into or submitted pursuant to the provisions of this Section may, in the Commission's discretion, be accorded proprietary treatment.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-510) (from Ch. 111 2/3, par. 13-510)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-510. Compensation of payphone providers. Any telecommunications carrier using the facilities or services of a payphone provider shall pay the provider just and reasonable compensation for the use of those facilities or services to complete billable operator services calls and for any other use that the Commission determines appropriate consistent with the provisions of this Act. The compensation shall be determined by the Commission subject to the provisions of this Act. This Section shall not apply to the extent a telecommunications carrier and a payphone provider have reached their own written compensation agreement.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-511)

Sec. 13-511. (Repealed).

(Source: P.A. 92-526, eff. 1-1-03. Repealed by P.A. 96-927, eff. 6-15-10.)

(220 ILCS 5/13-512)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-512. Rules; review. The Commission shall have general rulemaking authority to make rules necessary to enforce this Article. However, not later than 270 days after the effective date of this amendatory Act of 1997, and every 2 years thereafter, the Commission shall review all rules issued under this Article that apply to the operations or activities of any telecommunications carrier. The Commission shall, after notice and hearing, repeal or modify any rule it determines to be no longer in the public interest as the result of the reasonable availability of competitive telecommunications services.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-513)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-513. Waiver of rules. A telecommunications carrier may petition for waiver of the application of a rule issued pursuant to this Act. The burden of proof in establishing the right to a waiver shall be upon the petitioner. The petition shall include a demonstration that the waiver would not harm consumers and would not impede the development or operation of a competitive market. Upon such demonstration, the Commission may waive the application of a rule, but not the application of a provision of this Act. The Commission may conduct an investigation of the petition on its own motion or at the request of a potentially affected person. If no investigation is conducted, the waiver shall be deemed granted 30 days after the petition is filed.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-514)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-514. Prohibited actions of telecommunications carriers. A telecommunications carrier shall not knowingly impede the development of competition in any telecommunications service market. The following prohibited actions are considered per se impediments to the development of competition; however, the Commission is not limited in any manner to these enumerated impediments and may consider other actions which impede competition to be prohibited:

(1) unreasonably refusing or delaying interconnections or collocation or providing inferior connections to another telecommunications carrier;

(2) unreasonably impairing the speed, quality, or efficiency of services used by another telecommunications carrier;

(3) unreasonably denying a request of another provider for information regarding the technical design and features, geographic coverage, information necessary for the design of equipment, and traffic capabilities of the local exchange network except for proprietary information unless such information is subject to a proprietary agreement or protective order;

(4) unreasonably delaying access in connecting another telecommunications carrier to the local exchange network whose product or service requires novel or specialized access requirements;

(5) unreasonably refusing or delaying access by any person to another telecommunications carrier;

(6) unreasonably acting or failing to act in a manner that has a substantial adverse effect on the ability of another telecommunications carrier to provide service to its customers;

(7) unreasonably failing to offer services to customers in a local exchange, where a telecommunications carrier is certificated to provide service and has entered into an interconnection agreement for the provision of local exchange telecommunications services, with the intent to delay or impede the ability of the incumbent local exchange telecommunications carrier to provide inter-LATA telecommunications services;

(8) violating the terms of or unreasonably delaying implementation of an interconnection agreement entered into pursuant to Section 252 of the federal Telecommunications Act of 1996;

(9) unreasonably refusing or delaying access to or provision of operation support systems to another telecommunications carrier or providing inferior operation support systems to another telecommunications carrier;

(10) unreasonably failing to offer network elements that the Commission or the Federal Communications Commission has determined must be offered on an unbundled basis to another telecommunications carrier in a manner consistent with the Commission's or Federal Communications Commission's orders or rules requiring such offerings;

(11) violating the obligations of Section 13-801; and

(12) violating an order of the Commission regarding matters between telecommunications carriers.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-515)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-515. Enforcement.

(a) The following expedited procedures shall be used to enforce the provisions of Section 13-514 of this Act, provided that, for a violation of paragraph (8) of Section 13-514 to qualify for the expedited procedures of this Section, the violation must be in a manner that unreasonably delays, increases the cost, or impedes the availability of telecommunications services to consumers. However, the Commission, the complainant, and the respondent may mutually agree to adjust the procedures established in this Section.

(b) (Blank).

(c) No complaint may be filed under this Section until the complainant has first notified the respondent of the alleged violation and offered the respondent 48 hours to correct the situation. Provision of notice and the opportunity to correct the situation creates a rebuttable presumption of knowledge under Section 13-514. After the filing of a complaint under this Section, the parties may agree to follow the mediation process under Section 10-101.1 of this Act. The time periods specified in subdivision (d)(7) of this Section shall be tolled during the time spent in mediation under Section 10-101.1.

(d) A telecommunications carrier may file a complaint with the Commission alleging a violation of Section 13-514 in accordance with this subsection:

(1) The complaint shall be filed with the Chief Clerk of the Commission and shall be served in hand upon the respondent, the executive director, and the general counsel of the Commission at the time of the filing.

(2) A complaint filed under this subsection shall include a statement that the requirements of subsection (c) have been fulfilled and that the respondent did not correct the situation as requested.

(3) Reasonable discovery specific to the issue of the complaint may commence upon filing of the complaint. Requests for discovery must be served in hand and responses to discovery must be provided in hand to the requester within 14 days after a request for discovery is made.

(4) An answer and any other responsive pleading to the complaint shall be filed with the Commission and served in hand at the same time upon the complainant, the executive director, and the general counsel of the Commission within 7 days after the date on which the complaint is filed.

(5) If the answer or responsive pleading raises the issue that the complaint violates subsection (i) of this Section, the complainant may file a reply to such allegation within 3 days after actual service of such answer or responsive pleading. Within 4 days after the time for filing a reply has expired, the hearing officer or arbitrator shall either issue a written decision dismissing the complaint as frivolous in violation of subsection (i) of this Section including the reasons for such disposition or shall issue an order directing that the complaint shall proceed.

(6) A pre-hearing conference shall be held within 14 days after the date on which the complaint is filed.

(7) The hearing shall commence within 30 days of the date on which the complaint is filed. The hearing may be conducted by an administrative law judge or by an arbitrator. Parties and the Commission staff shall be entitled to present evidence and legal argument in oral or written form as deemed appropriate by the administrative law judge or arbitrator. The administrative law judge or arbitrator shall issue a written decision within 60 days after the date on which the complaint is filed. The decision shall include reasons for the disposition of the complaint and, if a violation of Section 13-514 is found, directions and a deadline for correction of the violation.

(8) Any party may file a petition requesting the Commission to review the decision of the administrative law judge or arbitrator within 5 days of such decision. Any party may file a response to a petition for review within 3 business days after actual service of the petition. After the time for filing of the petition for review, but no later than 15 days after the decision of the administrative law judge or arbitrator, the Commission shall decide to adopt the decision of the administrative law judge or arbitrator or shall issue its own final order.

(e) If the alleged violation has a substantial adverse effect on the ability of the complainant to provide service to customers, the complainant may include in its complaint a request for an order for emergency relief. The Commission, acting through its designated administrative law judge or arbitrator, shall act upon such a request within 2 business days of the filing of the complaint. An order for emergency relief may be granted, without an evidentiary hearing, upon a verified factual showing that the party seeking relief will likely succeed on the merits, that the party will suffer irreparable harm in its ability to serve customers if emergency relief is not granted, and that the order is in the public interest. An order for emergency relief shall include a finding that the requirements of this subsection have been fulfilled and shall specify the directives that must be fulfilled by the respondent and deadlines for meeting those directives. The decision of the administrative law judge or arbitrator to grant or deny emergency relief shall be considered an order of the Commission unless the Commission enters its own order within 2 calendar days of the decision of the administrative law judge or arbitrator. The order for emergency relief may require the responding party to act or refrain from acting so as to protect the provision of competitive service offerings to customers. Any action required by an emergency relief order must be technically feasible and economically reasonable and the respondent must be given a reasonable period of time to comply with the order.

(f) The Commission is authorized to obtain outside resources including, but not limited to, arbitrators and consultants for the purposes of the hearings authorized by this Section. Any arbitrator or consultant obtained by the Commission shall be approved by both parties to the hearing. The cost of such outside resources including, but not limited to, arbitrators and consultants shall be borne by the parties. The Commission shall review the bill for reasonableness and assess the parties for reasonable costs dividing the costs according to the resolution of the complaint brought under this Section. Such costs shall be paid by the parties directly to the arbitrators, consultants, and other providers of outside resources within 60 days after receiving notice of the assessments from the Commission. Interest at the statutory rate shall accrue after expiration of the 60-day period. The Commission, arbitrators, consultants, or other providers of outside resources may apply to a court of competent jurisdiction for an order requiring payment.

(g) The Commission shall assess the parties under this subsection for all of the Commission's costs of investigation and conduct of the proceedings brought under this Section including, but not limited to, the prorated salaries of staff, attorneys, administrative law judges, and support personnel and including any travel and per diem, directly attributable to the complaint brought pursuant to this Section, but excluding those costs provided for in subsection (f), dividing the costs according to the resolution of the complaint brought under this Section. All assessments made under this subsection shall be paid into the Public Utility Fund within 60 days after receiving notice of the assessments from the Commission. Interest at the statutory rate shall accrue after the expiration of the 60 day period. The Commission is authorized to apply to a court of competent jurisdiction for an order requiring payment.

(h) If the Commission determines that there is an imminent threat to competition or to the public interest, the Commission may, notwithstanding any other provision of this Act, seek temporary, preliminary, or permanent injunctive relief from a court of competent jurisdiction either prior to or after the hearing.

(i) A party shall not bring or defend a proceeding brought under this Section or assert or controvert an issue in a proceeding brought under this Section, unless there is a non-frivolous basis for doing so. By presenting a pleading, written motion, or other paper in complaint or defense of the actions or inaction of a party under this Section, a party is certifying to the Commission that to the best of that party's knowledge, information, and belief, formed after a reasonable inquiry of the subject matter of the complaint or defense, that the complaint or defense is well grounded in law and fact, and under the circumstances:

(1) it is not being presented to harass the other party, cause unnecessary delay in the provision of competitive telecommunications services to consumers, or create needless increases in the cost of litigation; and

(2) the allegations and other factual contentions have evidentiary support or, if specifically so identified, are likely to have evidentiary support after reasonable opportunity for further investigation or discovery as defined herein.

(j) If, after notice and a reasonable opportunity to respond, the Commission determines that subsection (i) has been violated, the Commission shall impose appropriate sanctions upon the party or parties that have violated subsection (i) or are responsible for the violation. The sanctions shall be not more than $30,000, plus the amount of expenses accrued by the Commission for conducting the hearing. Payment of sanctions imposed under this subsection shall be made to the Common School Fund within 30 days of imposition of such sanctions.

(k) An appeal of a Commission Order made pursuant to this Section shall not effectuate a stay of the Order unless a court of competent jurisdiction specifically finds that the party seeking the stay will likely succeed on the merits, that the party will suffer irreparable harm without the stay, and that the stay is in the public interest.

(Source: P.A. 100-20, eff. 7-1-17; 100-840, eff. 8-13-18.)

(220 ILCS 5/13-516)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-516. Enforcement remedies for prohibited actions by telecommunications carriers.

(a) In addition to any other provision of this Act, all of the following remedies may be applied for violations of Section 13-514, provided that, for a violation of paragraph (8) of Section 13-514 to qualify for the remedies in this Section, the violation must be in a manner that unreasonably delays, increases the cost, or impedes the availability of telecommunications services to consumers:

(1) A Commission order directing the violating telecommunications carrier to cease and desist from violating the Act or a Commission order or rule.

(2) Notwithstanding any other provision of this Act, for a second and any subsequent violation of Section 13-514 committed by a telecommunications carrier after the effective date of this amendatory Act of the 92nd General Assembly, the Commission may impose penalties of up to $30,000 or 0.00825% of the telecommunications carrier's gross intrastate annual telecommunications revenue, whichever is greater, per violation unless the telecommunications carrier has fewer than 35,000 subscriber access lines, in which case the civil penalty may not exceed $2,000 per violation. The second and any subsequent violation of Section 13-514 need not be of the same nature or provision of the Section for a penalty to be imposed. Matters resolved through voluntary mediation pursuant to Section 10-101.1 shall not be considered as a violation of Section 13-514 in computing eligibility for imposition of a penalty under this subdivision (a)(2). Each day of a continuing offense shall be treated as a separate violation for purposes of levying any penalty under this Section. The period for which the penalty shall be levied shall commence on the day the telecommunications carrier first violated Section 13-514 or on the day of the notice provided to the telecommunications carrier pursuant to subsection (c) of Section 13-515, whichever is later, and shall continue until the telecommunications carrier is in compliance with the Commission order. In assessing a penalty under this subdivision (a)(2), the Commission may consider mitigating factors, including those specified in items (1) through (4) of subsection (a) of Section 13-304.

(3) The Commission shall award damages, attorney's fees, and costs to any telecommunications carrier that was subjected to a violation of Section 13-514.

(b) The Commission may waive penalties imposed under subdivision (a)(2) if it makes a written finding as to its reasons for waiving the penalty. Reasons for waiving a penalty shall include, but not be limited to, technological infeasibility and acts of God.

(c) The Commission shall establish by rule procedures for the imposition of remedies under subsection (a) that, at a minimum, provide for notice, hearing and a written order relating to the imposition of remedies.

(d) Unless enforcement of an order entered by the Commission under Section 13-515 otherwise directs or is stayed by the Commission or by an appellate court reviewing the Commission's order, at any time after 30 days from the entry of the order, either the Commission, or the telecommunications carrier found by the Commission to have been subjected to a violation of Section 13-514, or both, is authorized to petition a court of competent jurisdiction for an order at law or in equity requiring enforcement of the Commission order. The court shall determine (1) whether the Commission entered the order identified in the petition and (2) whether the violating telecommunications carrier has complied with the Commission's order. A certified copy of a Commission order shall be prima facie evidence that the Commission entered the order so certified. Pending the court's resolution of the petition, the court may award temporary or preliminary injunctive relief, or such other equitable relief as may be necessary, to effectively implement and enforce the Commission's order in a timely manner.

If after a hearing the court finds that the Commission entered the order identified in the petition and that the violating telecommunications carrier has not complied with the Commission's order, the court shall enter judgment requiring the violating telecommunications carrier to comply with the Commission's order and order such relief at law or in equity as the court deems necessary to effectively implement and enforce the Commission's order in a timely manner. The court shall also award to the petitioner, or petitioners, attorney's fees and costs, which shall be taxed and collected as part of the costs of the case.

If the court finds that the violating telecommunications carrier has failed to comply with the timely payment of damages, attorney's fees, or costs ordered by the Commission, the court shall order the violating telecommunications carrier to pay to the telecommunications carrier or carriers awarded the damages, fees, or costs by the Commission additional damages for the sake of example and by way of punishment for the failure to timely comply with the order of the Commission, unless the court finds a reasonable basis for the violating telecommunications carrier's failure to make timely payment according to the Commission's order, in which instance the court shall establish a new date for payment to be made.

(e) Payment of damages, attorney's fees, and costs imposed under subsection (a) shall be made within 30 days after issuance of the Commission order imposing the penalties, damages, attorney's fees, or costs, unless otherwise directed by the Commission or a reviewing court under an appeal taken pursuant to Article X. Payment of penalties imposed under subsection (a) shall be made to the Common School Fund within 30 days of issuance of the Commission order imposing the penalties.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-517)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-517. Provision of advanced telecommunications services.

(a) Every Incumbent Local Exchange Carrier (telecommunications carrier that offers or provides a noncompetitive telecommunications service) shall offer or provide advanced telecommunications services to not less than 80% of its customers by January 1, 2005.

(b) The Commission is authorized to grant a full or partial waiver of the requirements of this Section upon verified petition of any Incumbent Local Exchange Carrier ("ILEC") which demonstrates that full compliance with the requirements of this Section would be unduly economically burdensome or technically infeasible or otherwise impractical in exchanges with low population density. Notice of any such petition must be given to all potentially affected customers. If no potentially affected customer requests the opportunity for a hearing on the waiver petition, the Commission may, in its discretion, allow the waiver request to take effect without hearing. The Commission shall grant such petition to the extent that, and for such duration as, the Commission determines that such waiver:

(1) is necessary:

(A) to avoid a significant adverse economic impact on users of telecommunications services generally;

(B) to avoid imposing a requirement that is unduly economically burdensome;

(C) to avoid imposing a requirement that is technically infeasible; or

(D) to avoid imposing a requirement that is otherwise impractical to implement in exchanges with low population density; and

(2) is consistent with the public interest, convenience, and necessity.

The Commission shall act upon any petition filed under this subsection within 180 days after receiving such petition. The Commission may by rule establish standards for granting any waiver of the requirements of this Section. The Commission may, upon complaint or on its own motion, hold a hearing to reconsider its grant of a waiver in whole or in part. In the event that the Commission, following hearing, determines that the affected ILEC no longer meets the requirements of item (2) of this subsection, the Commission shall by order rescind such waiver, in whole or in part. In the event and to the degree the Commission rescinds such waiver, the Commission shall establish an implementation schedule for compliance with the requirements of this Section.

(c) As used in this Section, "advanced telecommunications services" means services capable of supporting, in at least one direction, a speed in excess of 200 kilobits per second (kbps) to the network demarcation point at the subscriber's premises.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-518)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-518. Optional service packages.

(a) It is the intent of this Section to provide unlimited local service packages at prices that will result in savings for the average consumer. Each telecommunications carrier that provides competitive and noncompetitive services, and that is subject to an alternative regulation plan pursuant to Section 13-506.1 of this Article, shall provide, in addition to such other services as it offers, the following optional packages of services for a fixed monthly rate, which, along with the terms and conditions thereof, the Commission shall review, pursuant to Article IX of this Act, to determine whether such rates, terms, and conditions are fair, just, and reasonable.

(1) A budget package, which shall consist of residential access service and unlimited local calls.

(2) A flat rate package, which shall consist of residential access service, unlimited local calls, and the customer's choice of 2 vertical services as defined in this Section.

(3) An enhanced flat rate package, which shall consist of residential access service for 2 lines, unlimited local calls, the customer's choice of 2 vertical services as defined in this Section, and unlimited local toll service.

(b) Nothing in this Section or this Act shall be construed to prohibit any telecommunications carrier subject to this Section from charging customers who elect to take one of the groups of services offered pursuant to this Section, any applicable surcharges, fees, and taxes.

(c) The term "vertical services", when used in this Section, includes, but is not necessarily limited to, call waiting, call forwarding, 3-way calling, caller ID, call tracing, automatic callback, repeat dialing, and voicemail.

(d) The service packages described in this Section shall be defined as noncompetitive services.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-519)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-519. Fire alarm; discontinuance of service. When a telecommunications carrier initiates a discontinuance of service on a known emergency system or fire alarm system that is required by the local authority to be a dedicated phone line circuit to the central dispatch of the fire department or fire protection district or, if applicable, the police department, the telecommunications carrier shall also transmit a copy of the written notice of discontinuance to that local authority.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-601) (from Ch. 111 2/3, par. 13-601)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-601. Application of Article VII. The provisions of Article VII of this Act are applicable only to telecommunications carriers offering or providing noncompetitive telecommunications service, and the Commission's regulation thereof, except that (1) the approval of contracts and arrangements with affiliated interests required by paragraph (3) of Section 7-101 shall not apply to such telecommunications carriers provided that, except as provided in item (2), those contracts and arrangements shall be filed with the Commission and (2) affiliated interest contracts or arrangements entered into by such telecommunications carriers where the increased obligation thereunder does not exceed the lesser of $5,000,000 or 5% of such carrier's prior annual revenue from noncompetitive services are not required to be filed with the Commission.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-701) (from Ch. 111 2/3, par. 13-701)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-701. Notwithstanding any other provision of this Act to the contrary, the Commission has no power to supervise or control any telephone cooperative as respects assessment schedules or local service rates made or charged by such a cooperative on a nondiscriminatory basis. In addition, the Commission has no power to inquire into, or require the submission of, the terms, conditions or agreements by or under which telephone cooperatives are financed. A telephone cooperative shall file with the Commission either a copy of the annual financial report required by the Rural Electrification Administration, or the annual financial report required of other public utilities.

Sections 13-712 and 13-713 of this Act do not apply to telephone cooperatives.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-702) (from Ch. 111 2/3, par. 13-702)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-702. Every telecommunications carrier operating in this State shall receive, transmit and deliver, without discrimination or delay, the conversations, messages or other transmissions of every other telecommunications carrier with which a joint rate has been established or with whose line a physical connection may have been made.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-703) (from Ch. 111 2/3, par. 13-703)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-703. (a) The Commission shall design and implement a program whereby each telecommunications carrier providing local exchange service shall provide a telecommunications device capable of servicing the needs of those persons with a hearing or speech disability together with a single party line, at no charge additional to the basic exchange rate, to any subscriber who is certified as having a hearing or speech disability by a hearing instrument professional, as defined in the Hearing Instrument Consumer Protection Act, a speech-language pathologist, or a qualified State agency and to any subscriber which is an organization serving the needs of those persons with a hearing or speech disability as determined and specified by the Commission pursuant to subsection (d).

(b) The Commission shall design and implement a program, whereby each telecommunications carrier providing local exchange service shall provide a telecommunications relay system, using third party intervention to connect those persons having a hearing or speech disability with persons of normal hearing by way of intercommunications devices and the telephone system, making available reasonable access to all phases of public telephone service to persons who have a hearing or speech disability. In order to design a telecommunications relay system which will meet the requirements of those persons with a hearing or speech disability available at a reasonable cost, the Commission shall initiate an investigation and conduct public hearings to determine the most cost-effective method of providing telecommunications relay service to those persons who have a hearing or speech disability when using telecommunications devices and therein solicit the advice, counsel, and physical assistance of Statewide nonprofit consumer organizations that serve persons with hearing or speech disabilities in such hearings and during the development and implementation of the system. The Commission shall phase in this program, on a geographical basis, as soon as is practicable, but no later than June 30, 1990.

(c) The Commission shall establish a competitively neutral rate recovery mechanism that establishes charges in an amount to be determined by the Commission for each line of a subscriber to allow telecommunications carriers providing local exchange service to recover costs as they are incurred under this Section. Beginning no later than April 1, 2016, and on a yearly basis thereafter, the Commission shall initiate a proceeding to establish the competitively neutral amount to be charged or assessed to subscribers of telecommunications carriers and wireless carriers, Interconnected VoIP service providers, and consumers of prepaid wireless telecommunications service in a manner consistent with this subsection (c) and subsection (f) of this Section. The Commission shall issue its order establishing the competitively neutral amount to be charged or assessed to subscribers of telecommunications carriers and wireless carriers, Interconnected VoIP service providers, and purchasers of prepaid wireless telecommunications service on or prior to June 1 of each year, and such amount shall take effect June 1 of each year.

Telecommunications carriers, wireless carriers, Interconnected VoIP service providers, and sellers of prepaid wireless telecommunications service shall have 60 days from the date the Commission files its order to implement the new rate established by the order.

(d) The Commission shall determine and specify those organizations serving the needs of those persons having a hearing or speech disability that shall receive a telecommunications device and in which offices the equipment shall be installed in the case of an organization having more than one office. For the purposes of this Section, "organizations serving the needs of those persons with hearing or speech disabilities" means centers for independent living as described in Section 12a of the Rehabilitation of Persons with Disabilities Act and not-for-profit organizations whose primary purpose is serving the needs of those persons with hearing or speech disabilities. The Commission shall direct the telecommunications carriers subject to its jurisdiction and this Section to comply with its determinations and specifications in this regard.

(e) As used in this Section:

"Prepaid wireless telecommunications service" has the meaning given to that term under Section 10 of the Prepaid Wireless 9-1-1 Surcharge Act.

"Retail transaction" has the meaning given to that term under Section 10 of the Prepaid Wireless 9-1-1 Surcharge Act.

"Seller" has the meaning given to that term under Section 10 of the Prepaid Wireless 9-1-1 Surcharge Act.

"Telecommunications carrier providing local exchange service" includes, without otherwise limiting the meaning of the term, telecommunications carriers which are purely mutual concerns, having no rates or charges for services, but paying the operating expenses by assessment upon the members of such a company and no other person.

"Wireless carrier" has the meaning given to that term under Section 2 of the Emergency Telephone System Act.

(f) Interconnected VoIP service providers, sellers of prepaid wireless telecommunications service, and wireless carriers in Illinois shall collect and remit assessments determined in accordance with this Section in a competitively neutral manner in the same manner as a telecommunications carrier providing local exchange service. However, the assessment imposed on consumers of prepaid wireless telecommunications service shall be collected by the seller from the consumer and imposed per retail transaction as a percentage of that retail transaction on all retail transactions occurring in this State. The assessment on subscribers of wireless carriers and consumers of prepaid wireless telecommunications service shall not be imposed or collected prior to June 1, 2016.

Sellers of prepaid wireless telecommunications service shall remit the assessments to the Department of Revenue on the same form and in the same manner which they remit the fee collected under the Prepaid Wireless 9-1-1 Surcharge Act. For the purposes of display on the consumers' receipts, the rates of the fee collected under the Prepaid Wireless 9-1-1 Surcharge Act and the assessment under this Section may be combined. In administration and enforcement of this Section, the provisions of Sections 15 and 20 of the Prepaid Wireless 9-1-1 Surcharge Act (except subsections (a), (a-5), (b-5), (e), and (e-5) of Section 15 and subsections (c) and (e) of Section 20 of the Prepaid Wireless 9-1-1 Surcharge Act and, from June 29, 2015 (the effective date of Public Act 99-6), the seller shall be permitted to deduct and retain 3% of the assessments that are collected by the seller from consumers and that are remitted and timely filed with the Department) that are not inconsistent with this Section, shall apply, as far as practicable, to the subject matter of this Section to the same extent as if those provisions were included in this Section. Beginning on January 1, 2018, the seller is allowed to deduct and retain 3% of the assessments that are collected by the seller from consumers and that are remitted timely and timely filed with the Department, but only if the return is filed electronically as provided in Section 3 of the Retailers' Occupation Tax Act. Sellers who demonstrate that they do not have access to the Internet or demonstrate hardship in filing electronically may petition the Department to waive the electronic filing requirement. The Department shall deposit all assessments and penalties collected under this Section into the Illinois Telecommunications Access Corporation Fund, a special fund created in the State treasury. On or before the 25th day of each calendar month, the Department shall prepare and certify to the Comptroller the amount available to the Commission for distribution out of the Illinois Telecommunications Access Corporation Fund. The amount certified shall be the amount (not including credit memoranda) collected during the second preceding calendar month by the Department, plus an amount the Department determines is necessary to offset any amounts which were erroneously paid to a different taxing body or fund. The amount paid to the Illinois Telecommunications Access Corporation Fund shall not include any amount equal to the amount of refunds made during the second preceding calendar month by the Department to retailers under this Section or any amount that the Department determines is necessary to offset any amounts which were payable to a different taxing body or fund but were erroneously paid to the Illinois Telecommunications Access Corporation Fund. The Commission shall distribute all the funds to the Illinois Telecommunications Access Corporation and the funds may only be used in accordance with the provisions of this Section. The Department shall deduct 2% of all amounts deposited in the Illinois Telecommunications Access Corporation Fund during every year of remitted assessments. Of the 2% deducted by the Department, one-half shall be transferred into the Tax Compliance and Administration Fund to reimburse the Department for its direct costs of administering the collection and remittance of the assessment. The remaining one-half shall be transferred into the Public Utility Fund to reimburse the Commission for its costs of distributing to the Illinois Telecommunications Access Corporation the amount certified by the Department for distribution. The amount to be charged or assessed under subsections (c) and (f) is not imposed on a provider or the consumer for wireless Lifeline service where the consumer does not pay the provider for the service. Where the consumer purchases from the provider optional minutes, texts, or other services in addition to the federally funded Lifeline benefit, a consumer must pay the charge or assessment, and it must be collected by the seller according to this subsection (f).

Interconnected VoIP services shall not be considered an intrastate telecommunications service for the purposes of this Section in a manner inconsistent with federal law or Federal Communications Commission regulation.

(g) The provisions of this Section are severable under Section 1.31 of the Statute on Statutes.

(h) The Commission may adopt rules necessary to implement this Section.

(Source: P.A. 103-495, eff. 1-1-24.)

(220 ILCS 5/13-704) (from Ch. 111 2/3, par. 13-704)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-704. Each page of a billing statement which sets forth charges assessed against a customer by a telecommunications carrier for telecommunications service shall reflect the telephone number or customer account number to which the charges are being billed. If a telecommunications carrier offers electronic billing, customers may elect to have their bills sent electronically. Such bills shall be transmitted with instructions for payment. Information sent electronically shall be deemed to satisfy any requirement in this Section that such information be printed or written on a customer bill. Bills may be paid electronically or by the use of a customer-preferred financially accredited credit or debit methodology.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-705) (from Ch. 111 2/3, par. 13-705)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-705. Every telephone directory distributed after July 1, 1990 to the general public in this State which lists the calling numbers of telephones, of any telephone exchange located in this State, shall also contain a listing, at no additional charge, of any special calling number assigned to any telecommunication device for the deaf in use within the geographic area of coverage for the directory, unless the telephone company is notified by the telecommunication device subscriber that the subscriber does not wish the TDD number to be listed in the directory. Such listing shall include, but is not limited to, residential, commercial and governmental numbers with telecommunication device access and shall include a designation if the device is for print or display communication only or if it also accommodates voice transmission. In addition to the aforementioned requirements each telephone directory so distributed shall also contain a listing of any city and county emergency services and any police telecommunication device for the deaf calling numbers in the coverage area within this State which is included in the directory as well as the listing of the Illinois State Police emergency telecommunication device for the deaf calling number in Springfield. This emergency numbers listing shall be preceded by the words "Emergency Assistance for Deaf Persons" which shall be as legible and printed in the same size as all other emergency subheadings on the page; provided, that the provisions of this Section do not apply to those directories distributed solely for business advertising purposes, commonly known as classified directories.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-706) (from Ch. 111 2/3, par. 13-706)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-706. Except as provided in Section 13-707 of this Act, all essential telephones, all coin-operated phones and all emergency telephones sold, rented or distributed by any other means in this State after July 1, 1990 shall be hearing-aid compatible. The provisions of this Section shall not apply to any telephone that is manufactured before July 1, 1989.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-707) (from Ch. 111 2/3, par. 13-707)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-707. The following telephones shall be exempt from the requirements of Section 13-706 of this Act: telephones used with public mobile services; telephones used with private radio services; and cordless telephones. The exemption provided in this Section shall not apply with respect to cordless telephones manufactured or imported more than 3 years after September 19, 1988. The Commission shall periodically assess the appropriateness of continuing in effect the exemptions provided herein for public mobile service and private radio service telephones and report their findings to the General Assembly.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-708)

Sec. 13-708. (Repealed).

(Source: Repealed by P.A. 88-604, eff. 9-1-94.)

(220 ILCS 5/13-709)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-709. Orders of correction.

(a) A telecommunications carrier shall comply with orders of correction issued by the Department of Public Health under Section 5 of the Illinois Plumbing License Law.

(b) Upon receiving notification from the Department of Public Health that a telecommunications carrier has failed to comply with an order of correction, the Illinois Commerce Commission shall enforce the order.

(c) The good faith compliance by a telecommunications carrier with an order of the Department of Public Health or Illinois Commerce Commission to terminate service pursuant to Section 5 of the Illinois Plumbing License Law shall constitute a complete defense to any civil action brought against the telecommunications carrier arising from the termination of service.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-712)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-712. Basic local exchange service quality; customer credits.

(a) It is the intent of the General Assembly that every telecommunications carrier meet minimum service quality standards in providing noncompetitive basic local exchange service on a non-discriminatory basis to all classes of customers.

(b) Definitions:

(1) (Blank).

(2) "Basic local exchange service" means residential and business lines used for local exchange telecommunications service as defined in Section 13-204 of this Act, that have not been classified as competitive pursuant to either Section 13-502 or subdivision (c)(5) of Section 13-506.2 of this Act, excluding:

(A) services that employ advanced telecommunications capability as defined in Section 706(c)(1) of the federal Telecommunications Act of 1996;

(B) vertical services;

(C) company official lines; and

(D) records work only.

(3) "Link Up" refers to the Link Up Assistance program defined and established at 47 C.F.R. Section 54.411 et seq. as amended.

(c) The Commission shall promulgate service quality rules for basic local exchange service, which may include fines, penalties, customer credits, and other enforcement mechanisms. In developing such service quality rules, the Commission shall consider, at a minimum, the carrier's gross annual intrastate revenue; the frequency, duration, and recurrence of the violation; and the relative harm caused to the affected customer or other users of the network. In imposing fines, the Commission shall take into account compensation or credits paid by the telecommunications carrier to its customers pursuant to this Section in compensation for the violation found pursuant to this Section. These rules shall become effective within one year after the effective date of this amendatory Act of the 92nd General Assembly.

(d) The rules shall, at a minimum, require each telecommunications carrier to do all of the following:

(1) Install basic local exchange service within 5 business days after receipt of an order from the customer unless the customer requests an installation date that is beyond 5 business days after placing the order for basic service and to inform the customer of its duty to install service within this timeframe. If installation of service is requested on or by a date more than 5 business days in the future, the telecommunications carrier shall install service by the date requested. A telecommunications carrier offering basic local exchange service utilizing the network or network elements of another carrier shall install new lines for basic local exchange service within 3 business days after provisioning of the line or lines by the carrier whose network or network elements are being utilized is complete. This subdivision (d)(1) does not apply to the migration of a customer between telecommunications carriers, so long as the customer maintains dial tone.

(2) Restore basic local exchange service for a customer within 30 hours of receiving notice that a customer is out of service. This provision applies to service disruptions that occur when a customer switches existing basic local exchange service from one carrier to another.

(3) Keep all repair and installation appointments for basic local exchange service, when a customer premises visit requires a customer to be present.

(4) Inform a customer when a repair or installation appointment requires the customer to be present.

(e) The rules shall include provisions for customers to be credited by the telecommunications carrier for violations of basic local exchange service quality standards as described in subsection (d). The credits shall be applied on the statement issued to the customer for the next monthly billing cycle following the violation or following the discovery of the violation. The performance levels established in subsection (c) are solely for the purposes of consumer credits and shall not be used as performance levels for the purposes of assessing penalties under Section 13-305. At a minimum, the rules shall include the following:

(1) If a carrier fails to repair an out-of-service condition for basic local exchange service within 30 hours, the carrier shall provide a credit to the customer. If the service disruption is for over 30 hours but less than 48 hours, the credit must be equal to a pro-rata portion of the monthly recurring charges for all local services disrupted. If the service disruption is for more than 48 hours, but not more than 72 hours, the credit must be equal to at least 33% of one month's recurring charges for all local services disrupted. If the service disruption is for more than 72 hours, but not more than 96 hours, the credit must be equal to at least 67% of one month's recurring charges for all local services disrupted. If the service disruption is for more than 96 hours, but not more than 120 hours, the credit must be equal to one month's recurring charges for all local services disrupted. For each day or portion thereof that the service disruption continues beyond the initial 120-hour period, the carrier shall also provide an additional credit of $20 per day.

(2) If a carrier fails to install basic local exchange service as required under subdivision (d)(1), the carrier shall waive 50% of any installation charges, or in the absence of an installation charge or where installation is pursuant to the Link Up program, the carrier shall provide a credit of $25. If a carrier fails to install service within 10 business days after the service application is placed, or fails to install service within 5 business days after the customer's requested installation date, if the requested date was more than 5 business days after the date of the order, the carrier shall waive 100% of the installation charge, or in the absence of an installation charge or where installation is provided pursuant to the Link Up program, the carrier shall provide a credit of $50. For each day that the failure to install service continues beyond the initial 10 business days, or beyond 5 business days after the customer's requested installation date, if the requested date was more than 5 business days after the date of the order, the carrier shall also provide an additional credit of $20 per day until service is installed.

(3) If a carrier fails to keep a scheduled repair or installation appointment when a customer premises visit requires a customer to be present, the carrier shall credit the customer $25 per missed appointment. A credit required by this subsection does not apply when the carrier provides the customer notice of its inability to keep the appointment no later than 8 p.m. of the day prior to the scheduled date of the appointment.

(4) If the violation of a basic local exchange service quality standard is caused by a carrier other than the carrier providing retail service to the customer, the carrier providing retail service to the customer shall credit the customer as provided in this Section. The carrier causing the violation shall reimburse the carrier providing retail service the amount credited the customer. When applicable, an interconnection agreement shall govern compensation between the carrier causing the violation, in whole or in part, and the retail carrier providing the credit to the customer.

(5) (Blank).

(6) Credits required by this subsection do not apply if the violation of a service quality standard:

(i) occurs as a result of a negligent or willful act on the part of the customer;

(ii) occurs as a result of a malfunction of customer-owned telephone equipment or inside wiring;

(iii) occurs as a result of, or is extended by, an emergency situation as defined in Commission rules;

(iv) is extended by the carrier's inability to gain access to the customer's premises due to the customer missing an appointment, provided that the violation is not further extended by the carrier;

(v) occurs as a result of a customer request to change the scheduled appointment, provided that the violation is not further extended by the carrier;

(vi) occurs as a result of a carrier's right to refuse service to a customer as provided in Commission rules; or

(vii) occurs as a result of a lack of facilities where a customer requests service at a geographically remote location, a customer requests service in a geographic area where the carrier is not currently offering service, or there are insufficient facilities to meet the customer's request for service, subject to a carrier's obligation for reasonable facilities planning.

(7) The provisions of this subsection are cumulative and shall not in any way diminish or replace other civil or administrative remedies available to a customer or a class of customers.

(f) The rules shall require each telecommunications carrier to provide to the Commission, on a quarterly basis and in a form suitable for posting on the Commission's website, a public report that includes performance data for basic local exchange service quality of service. The performance data shall be disaggregated for each geographic area and each customer class of the State for which the telecommunications carrier internally monitored performance data as of a date 120 days preceding the effective date of this amendatory Act of the 92nd General Assembly. The report shall include, at a minimum, performance data on basic local exchange service installations, lines out of service for more than 30 hours, carrier response to customer calls, trouble reports, and missed repair and installation commitments.

(g) The Commission shall establish and implement carrier to carrier wholesale service quality rules and establish remedies to ensure enforcement of the rules.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-713)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-713. Consumer complaint resolution process.

(a) It is the intent of the General Assembly that consumer complaints against telecommunications carriers shall be concluded as expeditiously as possible consistent with the rights of the parties thereto to the due process of law and protection of the public interest.

(b) The Commission shall promulgate rules that permit parties to resolve disputes through mediation. A consumer may request mediation upon completion of the Commission's informal complaint process and prior to the initiation of a formal complaint as described in Commission rules.

(c) A residential consumer or business consumer with fewer than 20 lines shall have the right to request mediation for resolution of a dispute with a telecommunications carrier. The carrier shall be required to participate in mediation at the consumer's request.

(d) The Commission may retain the services of an independent neutral mediator or trained Commission staff to facilitate resolution of the consumer dispute. The mediation process must be completed no later than 45 days after the consumer requests mediation.

(e) If the parties reach agreement, the agreement shall be reduced to writing at the conclusion of the mediation. The writing shall contain mutual conditions, payment arrangements, or other terms that resolve the dispute in its entirety. If the parties are unable to reach agreement or after 45 days, whichever occurs first, the consumer may file a formal complaint with the Commission as described in Commission rules.

(f) If either the consumer or the carrier fails to abide by the terms of the settlement agreement, either party may exercise any rights it may have as specified in the terms of the agreement or as provided in Commission rules.

(g) All notes, writings and settlement discussions related to the mediation shall be exempt from discovery and shall be inadmissible in any agency or court proceeding.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-801) (from Ch. 111 2/3, par. 13-801)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-801. Incumbent local exchange carrier obligations.

(a) This Section provides additional State requirements contemplated by, but not inconsistent with, Section 261(c) of the federal Telecommunications Act of 1996, and not preempted by orders of the Federal Communications Commission. A telecommunications carrier not subject to regulation under an alternative regulation plan pursuant to Section 13-506.1 of this Act shall not be subject to the provisions of this Section, to the extent that this Section imposes requirements or obligations upon the telecommunications carrier that exceed or are more stringent than those obligations imposed by Section 251 of the federal Telecommunications Act of 1996 and regulations promulgated thereunder.

An incumbent local exchange carrier shall provide a requesting telecommunications carrier with interconnection, collocation, network elements, and access to operations support systems on just, reasonable, and nondiscriminatory rates, terms, and conditions to enable the provision of any and all existing and new telecommunications services within the LATA, including, but not limited to, local exchange and exchange access. The Commission shall require the incumbent local exchange carrier to provide interconnection, collocation, and network elements in any manner technically feasible to the fullest extent possible to implement the maximum development of competitive telecommunications services offerings. As used in this Section, to the extent that interconnection, collocation, or network elements have been deployed for or by the incumbent local exchange carrier or one of its wireline local exchange affiliates in any jurisdiction, it shall be presumed that such is technically feasible in Illinois.

(b) Interconnection.

(1) An incumbent local exchange carrier shall provide for the facilities and equipment of any requesting telecommunications carrier's interconnection with the incumbent local exchange carrier's network on just, reasonable, and nondiscriminatory rates, terms, and conditions:

(A) for the transmission and routing of local exchange, and exchange access telecommunications services;

(B) at any technically feasible point within the incumbent local exchange carrier's network; however, the incumbent local exchange carrier may not require the requesting carrier to interconnect at more than one technically feasible point within a LATA; and

(C) that is at least equal in quality and functionality to that provided by the incumbent local exchange carrier to itself or to any subsidiary, affiliate, or any other party to which the incumbent local exchange carrier provides interconnection.

(2) An incumbent local exchange carrier shall make available to any requesting telecommunications carrier, to the extent technically feasible, those services, facilities, or interconnection agreements or arrangements that the incumbent local exchange carrier or any of its incumbent local exchange subsidiaries or affiliates offers in another state under the terms and conditions, but not the stated rates, negotiated pursuant to Section 252 of the federal Telecommunications Act of 1996. Rates shall be established in accordance with the requirements of subsection (g) of this Section. An incumbent local exchange carrier shall also make available to any requesting telecommunications carrier, to the extent technically feasible, and subject to the unbundling provisions of Section 251(d)(2) of the federal Telecommunications Act of 1996, those unbundled network element or interconnection agreements or arrangements that a local exchange carrier affiliate of the incumbent local exchange carrier obtains in another state from the incumbent local exchange carrier in that state, under the terms and conditions, but not the stated rates, obtained through negotiation, or through an arbitration initiated by the affiliate, pursuant to Section 252 of the federal Telecommunications Act of 1996. Rates shall be established in accordance with the requirements of subsection (g) of this Section.

(c) Collocation. An incumbent local exchange carrier shall provide for physical or virtual collocation of any type of equipment for interconnection or access to network elements at the premises of the incumbent local exchange carrier on just, reasonable, and nondiscriminatory rates, terms, and conditions. The equipment shall include, but is not limited to, optical transmission equipment, multiplexers, remote switching modules, and cross-connects between the facilities or equipment of other collocated carriers. The equipment shall also include microwave transmission facilities on the exterior and interior of the incumbent local exchange carrier's premises used for interconnection to, or for access to network elements of, the incumbent local exchange carrier or a collocated carrier, unless the incumbent local exchange carrier demonstrates to the Commission that it is not practical due to technical reasons or space limitations. An incumbent local exchange carrier shall allow, and provide for, the most reasonably direct and efficient cross-connects, that are consistent with safety and network reliability standards, between the facilities of collocated carriers. An incumbent local exchange carrier shall also allow, and provide for, cross connects between a noncollocated telecommunications carrier's network elements platform, or a noncollocated telecommunications carrier's transport facilities, and the facilities of any collocated carrier, consistent with safety and network reliability standards.

(d) Network elements. The incumbent local exchange carrier shall provide to any requesting telecommunications carrier, for the provision of an existing or a new telecommunications service, nondiscriminatory access to network elements on any unbundled or bundled basis, as requested, at any technically feasible point on just, reasonable, and nondiscriminatory rates, terms, and conditions.

(1) An incumbent local exchange carrier shall provide unbundled network elements in a manner that allows requesting telecommunications carriers to combine those network elements to provide a telecommunications service.

(2) An incumbent local exchange carrier shall not separate network elements that are currently combined, except at the explicit direction of the requesting carrier.

(3) Upon request, an incumbent local exchange carrier shall combine any sequence of unbundled network elements that it ordinarily combines for itself, including but not limited to, unbundled network elements identified in The Draft of the Proposed Ameritech Illinois 271 Amendment (I2A) found in Schedule SJA-4 attached to Exhibit 3.1 filed by Illinois Bell Telephone Company on or about March 28, 2001 with the Illinois Commerce Commission under Illinois Commerce Commission Docket Number 00-0700. The Commission shall determine those network elements the incumbent local exchange carrier ordinarily combines for itself if there is a dispute between the incumbent local exchange carrier and the requesting telecommunications carrier under this subdivision of this Section of this Act.

The incumbent local exchange carrier shall be entitled to recover from the requesting telecommunications carrier any just and reasonable special construction costs incurred in combining such unbundled network elements (i) if such costs are not already included in the established price of providing the network elements, (ii) if the incumbent local exchange carrier charges such costs to its retail telecommunications end users, and (iii) if fully disclosed in advance to the requesting telecommunications carrier. The Commission shall determine whether the incumbent local exchange carrier is entitled to any special construction costs if there is a dispute between the incumbent local exchange carrier and the requesting telecommunications carrier under this subdivision of this Section of this Act.

(4) A telecommunications carrier may use a network elements platform consisting solely of combined network elements of the incumbent local exchange carrier to provide end to end telecommunications service for the provision of existing and new local exchange, interexchange that includes local, local toll, and intraLATA toll, and exchange access telecommunications services within the LATA to its end users or payphone service providers without the requesting telecommunications carrier's provision or use of any other facilities or functionalities.

(5) The Commission shall establish maximum time periods for the incumbent local exchange carrier's provision of network elements. The maximum time period shall be no longer than the time period for the incumbent local exchange carrier's provision of comparable retail telecommunications services utilizing those network elements. The Commission may establish a maximum time period for a particular network element that is shorter than for a comparable retail telecommunications service offered by the incumbent local exchange carrier if a requesting telecommunications carrier establishes that it shall perform other functions or activities after receipt of the particular network element to provide telecommunications services to end users. The burden of proof for establishing a maximum time period for a particular network element that is shorter than for a comparable retail telecommunications service offered by the incumbent local exchange carrier shall be on the requesting telecommunications carrier. Notwithstanding any other provision of this Article, unless and until the Commission establishes by rule or order a different specific maximum time interval, the maximum time intervals shall not exceed 5 business days for the provision of unbundled loops, both digital and analog, 10 business days for the conditioning of unbundled loops or for existing combinations of network elements for an end user that has existing local exchange telecommunications service, and one business day for the provision of the high frequency portion of the loop (line-sharing) for at least 95% of the requests of each requesting telecommunications carrier for each month.

In measuring the incumbent local exchange carrier's actual performance, the Commission shall ensure that occurrences beyond the control of the incumbent local exchange carrier that adversely affect the incumbent local exchange carrier's performance are excluded when determining actual performance levels. Such occurrences shall be determined by the Commission, but at a minimum must include work stoppage or other labor actions and acts of war. Exclusions shall also be made for performance that is governed by agreements approved by the Commission and containing timeframes for the same or similar measures or for when a requesting telecommunications carrier requests a longer time interval.

(6) When a telecommunications carrier requests a network elements platform referred to in subdivision (d)(4) of this Section, without the need for field work outside of the central office, for an end user that has existing local exchange telecommunications service provided by an incumbent local exchange carrier, or by another telecommunications carrier through the incumbent local exchange carrier's network elements platform, unless otherwise agreed by the telecommunications carriers, the incumbent local exchange carrier shall provide the requesting telecommunications carrier with the requested network elements platform within 3 business days for at least 95% of the requests for each requesting telecommunications carrier for each month. A requesting telecommunications carrier may order the network elements platform as is for an end user that has such existing local exchange service without changing any of the features previously selected by the end user. The incumbent local exchange carrier shall provide the requested network elements platform without any disruption to the end user's services.

Absent a contrary agreement between the telecommunications carriers entered into after the effective date of this amendatory Act of the 92nd General Assembly, as of 12:01 a.m. on the third business day after placing the order for a network elements platform, the requesting telecommunications carrier shall be the presubscribed primary local exchange carrier for that end user line and shall be entitled to receive, or to direct the disposition of, all revenues for all services utilizing the network elements in the platform, unless it is established that the end user of the existing local exchange service did not authorize the requesting telecommunications carrier to make the request.

(e) Operations support systems. The Commission shall establish minimum standards with just, reasonable, and nondiscriminatory rates, terms, and conditions for the preordering, ordering, provisioning, maintenance and repair, and billing functions of the incumbent local exchange carrier's operations support systems provided to other telecommunications carriers.

(f) Resale. An incumbent local exchange carrier shall offer all retail telecommunications services, that the incumbent local exchange carrier provides at retail to subscribers who are not telecommunications carriers, within the LATA, together with each applicable optional feature or functionality, subject to resale at wholesale rates without imposing any unreasonable or discriminatory conditions or limitations. Wholesale rates shall be based on the retail rates charged to end users for the telecommunications service requested, excluding the portion thereof attributable to any marketing, billing, collection, and other costs avoided by the local exchange carrier. The Commission may determine under Article IX of this Act that certain noncompetitive services, together with each applicable optional feature or functionality, that are offered to residence customers under different rates, charges, terms, or conditions than to other customers should not be subject to resale under the rates, charges, terms, or conditions available only to residence customers.

(g) Cost based rates. Interconnection, collocation, network elements, and operations support systems shall be provided by the incumbent local exchange carrier to requesting telecommunications carriers at cost based rates. The immediate implementation and provisioning of interconnection, collocation, network elements, and operations support systems shall not be delayed due to any lack of determination by the Commission as to the cost based rates. When cost based rates have not been established, within 30 days after the filing of a petition for the setting of interim rates, or after the Commission's own motion, the Commission shall provide for interim rates that shall remain in full force and effect until the cost based rate determination is made, or the interim rate is modified, by the Commission.

(h) Rural exemption. This Section does not apply to certain rural telephone companies as described in 47 U.S.C. 251(f).

(i) Schedule of rates. A telecommunications carrier may request the incumbent local exchange carrier to provide a schedule of rates listing each of the rate elements of the incumbent local exchange carrier that pertains to a proposed order identified by the requesting telecommunications carrier for any of the matters covered in this Section. The incumbent local exchange carrier shall deliver the requested schedule of rates to the requesting telecommunications carrier within 2 business days for 95% of the requests for each requesting carrier

(j) Special access circuits. Other than as provided in subdivision (d)(4) of this Section for the network elements platform described in that subdivision, nothing in this amendatory Act of the 92nd General Assembly is intended to require or prohibit the substitution of switched or special access services by or with a combination of network elements nor address the Illinois Commerce Commission's jurisdiction or authority in this area.

(k) The Commission shall determine any matters in dispute between the incumbent local exchange carrier and the requesting carrier pursuant to Section 13-515 of this Act.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-802)

Sec. 13-802. (Repealed).

(Source: P.A. 84-1063. Repealed by P.A. 96-927, eff. 6-15-10.)

(220 ILCS 5/13-802.1)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-802.1. Depreciation; examination and audit; agreement conditions; federal Telecommunications Act of 1996.

(a) In performing any cost analysis authorized pursuant to this Act, the Commission may ascertain and determine and by order fix the proper and adequate rate of depreciation of the property for a telecommunications carrier for the purpose of such cost analysis.

(b) The Commission may provide for the examination and audit of all accounts. Items subject to the Commission's regulatory requirements shall be so allocated in the manner prescribed by the Commission. The officers and employees of the Commission shall have the authority under the direction of the Commission to inspect and examine any and all books, accounts, papers, records, and memoranda kept by the telecommunications carrier.

(c) The Commission is authorized to adopt rules and regulations concerning the conditions to be contained in and become a part of contracts for noncompetitive telecommunications services in a manner consistent with this Act and federal law.

(d) The Commission shall have the authority to, and shall engage in, all state regulatory actions needed to implement and enforce the federal Telecommunications Act of 1996 consistent with federal law, including, but not limited to, the negotiation, arbitration, implementation, resolution of disputes and enforcement of interconnection agreements arising under Sections 251 and 252 of the federal Telecommunications Act of 1996.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-803) (from Ch. 111 2/3, par. 13-803)

Sec. 13-803. (Repealed).

(Source: P.A. 90-185, eff. 7-23-97. Repealed by P.A. 92-22, eff. 6-30-01.)

(220 ILCS 5/13-804)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-804. Broadband investment. Increased investment into broadband infrastructure is critical to the economic development of this State and a key component to the retention of existing jobs and the creation of new jobs. The removal of regulatory uncertainty will attract greater private-sector investment in broadband infrastructure. Notwithstanding other provisions of this Article:

(A) the Commission shall have the authority to certify providers of wireless services, including, but not limited to, private radio service, public mobile service, or commercial mobile service, as those terms are defined in 47 U.S.C. 332 on the effective date of this amendatory Act of the 96th General Assembly or as amended thereafter, to provide telecommunications services in Illinois;

(B) the Commission shall have the authority to certify providers of wireless services, including, but not limited to, private radio service, public mobile service, or commercial mobile service, as those terms are defined in 47 U.S.C. 332 on the effective date of this amendatory Act of the 96th General Assembly or as amended thereafter, as eligible telecommunications carriers in Illinois, as that term has the meaning prescribed in 47 U.S.C. 214 on the effective date of this amendatory Act of the 96th General Assembly or as amended thereafter;

(C) the Commission shall have the authority to register providers of fixed or non-nomadic Interconnected VoIP service as Interconnected VoIP service providers in Illinois in accordance with Section 401.1 of this Article;

(D) the Commission shall have the authority to require providers of Interconnected VoIP service to participate in hearing and speech disability programs; and

(E) the Commission shall have the authority to access information provided to the non-profit organization under Section 20 of the High Speed Internet Services and Information Technology Act, provided the Commission enters into a proprietary and confidentiality agreement governing such information.

Except to the extent expressly permitted by and consistent with federal law, the regulations of the Federal Communications Commission, this Article, Article XXI or XXII of this Act, or this amendatory Act of the 96th General Assembly, the Commission shall not regulate the rates, terms, conditions, quality of service, availability, classification, or any other aspect of service regarding (i) broadband services, (ii) Interconnected VoIP services, (iii) information services, as defined in 47 U.S.C. 153(20) on the effective date of this amendatory Act of the 96th General Assembly or as amended thereafter, or (iv) wireless services, including, but not limited to, private radio service, public mobile service, or commercial mobile service, as those terms are defined in 47 U.S.C. 332 on the effective date of this amendatory Act of the 96th General Assembly or as amended thereafter.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-900)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-900. Authority to serve as 9-1-1 system provider; rules.

(a) The General Assembly finds that it is necessary to require the certification of 9-1-1 system providers to ensure the safety of the lives and property of Illinoisans and Illinois businesses, and to otherwise protect and promote the public safety, health, and welfare of the citizens of this State and their property.

(b) For purposes of this Section:

"9-1-1 system" has the same meaning as that term is defined in Section 2.19 of the Emergency Telephone System Act.

"9-1-1 system provider" means any person, corporation, limited liability company, partnership, sole proprietorship, or entity of any description whatever that acts as a system provider within the meaning of Section 2.18 of the Emergency Telephone System Act.

"Emergency Telephone System Board" has the same meaning as that term is defined in Sections 2.11 and 15.4 of the Emergency Telephone System Act.

"Public safety agency personnel" means personnel employed by a public safety agency, as that term is defined in Section 2.02 of the Emergency Telephone System Act, whose responsibilities include responding to requests for emergency services.

(c) Except as otherwise provided in this Section, beginning July 1, 2010, it is unlawful for any 9-1-1 system provider to offer or provide or seek to offer or provide to any emergency telephone system board or 9-1-1 system, or agent, representative, or designee thereof, any network and database service used or intended to be used by any emergency telephone system board or 9-1-1 system for the purpose of answering, transferring, or relaying requests for emergency services, or dispatching public safety agency personnel in response to requests for emergency services, unless the 9-1-1 system provider has applied for and received a Certificate of 9-1-1 System Provider Authority from the Commission. The Commission shall approve an application for a Certificate of 9-1-1 System Provider Authority upon a showing by the applicant, and a finding by the Commission, after notice and hearing, that the applicant possesses sufficient technical, financial, and managerial resources and abilities to provide network service and database services that it seeks authority to provide in its application for service authority, in a safe, continuous, and uninterrupted manner.

(d) No incumbent local exchange carrier that provides, as of the effective date of this amendatory Act of the 96th General Assembly, any 9-1-1 network and 9-1-1 database service used or intended to be used by any Emergency Telephone System Board or 9-1-1 system, shall be required to obtain a Certificate of 9-1-1 System Provider Authority under this Section. No entity that possesses, as of the effective date of this amendatory Act of the 96th General Assembly, a Certificate of Service Authority and provides 9-1-1 network and 9-1-1 database services to any incumbent local exchange carrier as of the effective date of this amendatory Act of the 96th General Assembly shall be required to obtain a Certificate of 9-1-1 System Provider Authority under this Section.

(e) Any and all enforcement authority granted to the Commission under this Section shall apply exclusively to 9-1-1 system providers granted a Certificate of Service Authority under this Section and shall not apply to incumbent local exchange carriers that are providing 9-1-1 service as of the effective date of this amendatory Act of the 96th General Assembly.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-900.1)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-900.1. Authority over 9-1-1 rates and terms of service. Notwithstanding any other provision of this Article, the Commission retains its full authority over the rates and service quality as they apply to 9-1-1 system providers, including the Commission's existing authority over interconnection with 9-1-1 system providers and 9-1-1 systems. The rates, terms, and conditions for 9-1-1 service shall be tariffed and shall be provided in the manner prescribed by this Act and shall be subject to the applicable laws, including rules or regulations adopted and orders issued by the Commission or the Federal Communications Commission. The Commission retains this full authority regardless of the technologies utilized or deployed by 9-1-1 system providers.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-900.2)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-900.2. Access services.

(a) This Section shall apply to switched access rates charged by all carriers other than Electing Providers whose switched access rates are governed by subsection (g) of Section 13-506.2 of this Act.

(b) Except as otherwise provided in subsection (c) of this Section, the rates of any telecommunications carrier, including, but not limited to, competitive local exchange carriers, providing intrastate switched access service shall be reduced to rates no higher than the carrier's rates for interstate switched access service as follows:

(1) by January 1, 2011, each telecommunications carrier must reduce its intrastate switched access rates by an amount equal to 50% of the difference between its then current intrastate switched access rates and its then current interstate switched access rates;

(2) by January 1, 2012, each telecommunications carrier must further reduce its intrastate switched access rates by an amount equal to 50% of the difference between its then current intrastate switched access rates and its then current interstate switched access rates;

(3) by July 1, 2012, each telecommunications carrier must reduce its intrastate switched access rates to mirror its then current interstate switched access rates and rate structure.

Following 24 months after the effective date of this amendatory Act of the 96th General Assembly, each telecommunications carrier must continue to set its intrastate switched access rates to mirror its interstate switched access rates and rate structure. For purposes of this Section, the rate for intrastate switched access service means the composite, per-minute rate for that service, including all applicable fixed and traffic-sensitive charges, including, but not limited to, carrier common line charges.

(c) Subsection (b) of this Section shall not apply to incumbent local exchange carriers serving 35,000 or fewer access lines.

(d) Nothing in subsection (b) of this Section prohibits a telecommunications carrier from electing to offer intrastate switched access service at rates lower than its interstate rates.

(e) The Commission shall have no authority to order a telecommunications carrier to set its rates for intrastate switched access at a level lower than its interstate switched access rates.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-900.3)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-900.3. Regulatory flexibility for 9-1-1 system providers.

(a) For purposes of this Section, "Regional Pilot Project" to implement next generation 9-1-1 has the same meaning as that term is defined in Section 2.22 of the Emergency Telephone System Act.

(b) For the limited purpose of a Regional Pilot Project to implement next generation 9-1-1, as defined in Section 13-900 of this Article, the Commission may forbear from applying any rule or provision of Section 13-900 as it applies to implementation of the Regional Pilot Project to implement next generation 9-1-1 if the Commission determines, after notice and hearing, that: (1) enforcement of the rule is not necessary to ensure the development and improvement of emergency communication procedures and facilities in such a manner as to be able to quickly respond to any person requesting 9-1-1 services from police, fire, medical, rescue, and other emergency services; (2) enforcement of the rule or provision is not necessary for the protection of consumers; and (3) forbearance from applying such provisions or rules is consistent with the public interest. The Commission may exercise such forbearance with respect to one, and only one, Regional Pilot Project as authorized by Sections 10 and 11 of the Emergency Telephone Systems Act to implement next generation 9-1-1.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-901) (from Ch. 111 2/3, par. 13-901)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-901. Operator service provider.

(a) For the purposes of this Section:

(1) "Operator service provider" means every telecommunications carrier that provides operator services or any other person or entity that the Commission determines is providing operator services.

(2) "Aggregator" means any person or entity that is not an operator service provider and that in the ordinary course of its operations makes telephones available to the public or to transient users of its premises including, but not limited to, a hotel, motel, hospital, or university for telephone calls between points within this State that are specified by the user using an operator service provider.

(3) "Operator services" means any telecommunications service that includes, as a component, any automatic or live assistance to a consumer to arrange for billing or completion, or both, of a telephone call between points within this State that are specified by the user through a method other than:

(A) automatic completion with billing to the telephone from which the call originated;

(B) completion through an access code or a proprietory account number used by the consumer, with billing to an account previously established with the carrier by the consumer; or

(C) completion in association with directory assistance services.

(b) The Commission shall, by rule or order, adopt and enforce operating requirements for the provision of operator-assisted services. The rules shall apply to operator service providers and to aggregators. The rules shall be compatible with the rules adopted by the Federal Communications Commission under the federal Telephone Operator Consumer Services Improvement Act of 1990. These requirements shall address, but not necessarily be limited to, the following:

(1) oral and written notification of the identity of the operator service provider and the availability of information regarding operator service provider rates, collection methods, and complaint resolution methods;

(2) restrictions on billing and charges for operator services;

(3) restrictions on "call splashing" as that term is defined in 47 C.F.R. Section 64.708;

(4) access to other telecommunications carriers by the use of access codes including, but not limited to 800, 888, 950, and 10XXX numbers;

(5) the appropriate routing and handling of emergency calls;

(6) the enforcement of these rules through tariffs for operator services and by a requirement that operator service providers withhold payment of compensation to aggregators that have been found to be noncomplying by the Commission.

(c) The Commission shall adopt any rule necessary to make rules previously adopted under this Section compatible with the rules of the Federal Communications Commission no later than one year after the effective date of this amendatory Act of 1993.

(d) A violation of any rule adopted by the Commission under subsection (b) is a business offense subject to a fine of not less than $1,000 nor more than $5,000. In addition, the Commission may, after notice and hearing, order any telecommunications carrier to terminate service to any aggregator found to have violated any rule.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-902)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-902. Authorization and verification of a subscriber's change in telecommunications carrier.

(a) Definitions; scope.

(1) "Submitting carrier" means any telecommunications carrier that requests on behalf of a subscriber that the subscriber's telecommunications carrier be changed and seeks to provide retail services to the end user subscriber.

(2) "Executing carrier" means any telecommunications carrier that effects a request that a subscriber's telecommunications carrier be changed.

(3) "Authorized carrier" means any telecommunications carrier that submits a change, on behalf of a subscriber, in the subscriber's selection of a provider of telecommunications service with the subscriber's authorization verified in accordance with the procedures specified in this Section.

(4) "Unauthorized carrier" means any telecommunications carrier that submits a change, on behalf of a subscriber, in the subscriber's selection of a provider of telecommunications service but fails to obtain the subscriber's authorization verified in accordance with the procedures specified in this Section.

(5) "Unauthorized change" means a change in a subscriber's selection of a provider of telecommunications service that was made without authorization verified in accordance with the verification procedures specified in this Section.

(6) "Subscriber" means:

(A) the party identified in the account records of a common carrier as responsible for payment of the telephone bill;

(B) any adult person authorized by such party to change telecommunications services or to charge services to the account; or

(C) any person contractually or otherwise lawfully authorized to represent such party.

This Section does not apply to retail business subscribers served by more than 20 lines.

(b) Authorization from the subscriber. "Authorization" means an express, affirmative act by a subscriber agreeing to the change in the subscriber's telecommunications carrier to another carrier. A subscriber's telecommunications service shall be provided by the telecommunications carrier selected by the subscriber.

(c) Authorization and verification of orders for telecommunications service.

(1) No telecommunications carrier shall submit or execute a change on behalf of a subscriber in the subscriber's selection of a provider of telecommunications service except in accordance with the procedures prescribed in this subsection.

(2) No submitting carrier shall submit a change on the behalf of a subscriber in the subscriber's selection of a provider of telecommunications service prior to obtaining:

(A) authorization from the subscriber; and

(B) verification of that authorization in accordance with the procedures prescribed in this Section.

The submitting carrier shall maintain and preserve records of verification of subscriber authorization for a minimum period of 2 years after obtaining such verification.

(3) An executing carrier shall not verify the submission of a change in a subscriber's selection of a provider of telecommunications service received from a submitting carrier. For an executing carrier, compliance with the procedures described in this Section shall be defined as prompt execution, without any unreasonable delay, of changes that have been verified by a submitting carrier.

(4) Commercial mobile radio services (CMRS) providers shall be excluded from the verification requirements of this Section as long as they are not required to provide equal access to common carriers for the provision of telephone toll services, in accordance with 47 U.S.C. 332(c)(8).

(5) Where a telecommunications carrier is selling more than one type of telecommunications service (e.g., local exchange, intraLATA/intrastate toll, interLATA/interstate toll, and international toll), that carrier must obtain separate authorization from the subscriber for each service sold, although the authorizations may be made within the same solicitation. Each authorization must be verified separately from any other authorizations obtained in the same solicitation. Each authorization must be verified in accordance with the verification procedures prescribed in this Section.

(6) No telecommunications carrier shall submit a preferred carrier change order unless and until the order has been confirmed in accordance with one of the following procedures:

(A) The telecommunications carrier has obtained the subscriber's written or electronically signed authorization in a form that meets the requirements of subsection (d).

(B) The telecommunications carrier has obtained the subscriber's electronic authorization to submit the preferred carrier change order. Such authorization must be placed from the telephone number or numbers on which the preferred carrier is to be changed and must confirm the information in subsections (b) and (c) of this Section. Telecommunications carriers electing to confirm sales electronically shall establish one or more toll-free telephone numbers exclusively for that purpose. Calls to the toll-free telephone numbers must connect a subscriber to a voice response unit, or similar mechanism, that records the required information regarding the preferred carrier change, including automatically recording the originating automatic number identification.

(C) An appropriately qualified independent third party has obtained, in accordance with the procedures set forth in paragraphs (7) through (10) of this subsection, the subscriber's oral authorization to submit the preferred carrier change order that confirms and includes appropriate verification data. The independent third party must not be owned, managed, controlled, or directed by the carrier or the carrier's marketing agent; must not have any financial incentive to confirm preferred carrier change orders for the carrier or the carrier's marketing agent; and must operate in a location physically separate from the carrier or the carrier's marketing agent.

(7) Methods of third party verification. Automated third party verification systems and three-way conference calls may be used for verification purposes so long as the requirements of paragraphs (8) through (10) of this subsection are satisfied.

(8) Carrier initiation of third party verification. A carrier or a carrier's sales representative initiating a three-way conference call or a call through an automated verification system must drop off the call once the three-way connection has been established.

(9) Requirements for content and format of third party verification. All third party verification methods shall elicit, at a minimum, the identity of the subscriber; confirmation that the person on the call is authorized to make the carrier change; confirmation that the person on the call wants to make the carrier change; the names of the carriers affected by the change; the telephone numbers to be switched; and the types of service involved. Third party verifiers may not market the carrier's services by providing additional information, including information regarding preferred carrier freeze procedures.

(10) Other requirements for third party verification. All third party verifications shall be conducted in the same language that was used in the underlying sales transaction and shall be recorded in their entirety. In accordance with the procedures set forth in paragraph (2)(B) of this subsection, submitting carriers shall maintain and preserve audio records of verification of subscriber authorization for a minimum period of 2 years after obtaining such verification. Automated systems must provide consumers with an option to speak with a live person at any time during the call.

(11) Telecommunications carriers must provide subscribers the option of using one of the authorization and verification procedures specified in paragraph (6) of this subsection in addition to an electronically signed authorization and verification procedure under paragraph (6)(A) of this subsection.

(d) Letter of agency form and content.

(1) A telecommunications carrier may use a written or electronically signed letter of agency to obtain authorization or verification, or both, of a subscriber's request to change his or her preferred carrier selection. A letter of agency that does not conform with this Section is invalid for purposes of this Section.

(2) The letter of agency shall be a separate document (or an easily separable document) or located on a separate screen or webpage containing only the authorizing language described in paragraph (5) of this subsection having the sole purpose of authorizing a telecommunications carrier to initiate a preferred carrier change. The letter of agency must be signed and dated by the subscriber to the telephone line or lines requesting the preferred carrier change.

(3) The letter of agency shall not be combined on the same document, screen, or webpage with inducements of any kind.

(4) Notwithstanding paragraphs (2) and (3) of this subsection, the letter of agency may be combined with checks that contain only the required letter of agency language as prescribed in paragraph (5) of this subsection and the necessary information to make the check a negotiable instrument. The letter of agency check shall not contain any promotional language or material. The letter of agency check shall contain in easily readable, bold-face type on the front of the check, a notice that the subscriber is authorizing a preferred carrier change by signing the check. The letter of agency language shall be placed near the signature line on the back of the check.

(5) At a minimum, the letter of agency must be printed with a type of sufficient size and readability to be clearly legible and must contain clear and unambiguous language that confirms:

(A) The subscriber's billing name and address and each telephone number to be covered by the preferred carrier change order;

(B) The decision to change the preferred carrier from the current telecommunications carrier to the soliciting telecommunications carrier;

(C) That the subscriber designates (insert the name of the submitting carrier) to act as the subscriber's agent for the preferred carrier change;

(D) That the subscriber understands that only one telecommunications carrier may be designated as the subscriber's interstate or interLATA preferred interexchange carrier for any one telephone number. To the extent that a jurisdiction allows the selection of additional preferred carriers (e.g., local exchange, intraLATA/intrastate toll, interLATA/interstate toll, or international interexchange) the letter of agency must contain separate statements regarding those choices, although a separate letter of agency for each choice is not necessary; and

(E) That the subscriber may consult with the carrier as to whether a fee will apply to the change in the subscriber's preferred carrier.

(6) Any carrier designated in a letter of agency as a preferred carrier must be the carrier directly setting the rates for the subscriber.

(7) Letters of agency shall not suggest or require that a subscriber take some action in order to retain the subscriber's current telecommunications carrier.

(8) If any portion of a letter of agency is translated into another language then all portions of the letter of agency must be translated into that language. Every letter of agency must be translated into the same language as any promotional materials, oral descriptions, or instructions provided with the letter of agency.

(9) Letters of agency submitted with an electronically signed authorization must include the consumer disclosures required by Section 101(c) of the Electronic Signatures in Global and National Commerce Act.

(10) A telecommunications carrier shall submit a preferred carrier change order on behalf of a subscriber within no more than 60 days after obtaining a written or electronically signed letter of agency.

(11) If a telecommunications carrier uses a letter of agency, the carrier shall send a letter to the subscriber using first class mail, postage prepaid, no later than 10 days after the telecommunications carrier submitting the change in the subscriber's telecommunications carrier is on notice that the change has occurred. The letter must inform the subscriber of the details of the telecommunications carrier change and provide the subscriber with a toll free number to call should the subscriber wish to cancel the change.

(e) A switch in a subscriber's selection of a provider of telecommunications service that complies with the rules promulgated by the Federal Communications Commission and any amendments thereto shall be deemed to be in compliance with the provisions of this Section.

(f) The Commission shall promulgate any rules necessary to administer this Section. The rules promulgated under this Section shall comport with the rules, if any, promulgated by the Attorney General pursuant to the Consumer Fraud and Deceptive Business Practices Act and with any rules promulgated by the Federal Communications Commission.

(g) Complaints may be filed with the Commission under this Section by a subscriber whose telecommunications service has been provided by an unauthorized telecommunications carrier as a result of an unreasonable delay, by a subscriber whose telecommunications carrier has been changed to another telecommunications carrier in a manner not in compliance with this Section, by a subscriber's authorized telecommunications carrier that has been removed as a subscriber's telecommunications carrier in a manner not in compliance with this Section, by a subscriber's authorized submitting carrier whose change order was delayed unreasonably, or by the Commission on its own motion. Upon filing of the complaint, the parties may mutually agree to submit the complaint to the Commission's established mediation process. Remedies in the mediation process may include, but shall not be limited to, the remedies set forth in this subsection. In its discretion, the Commission may deny the availability of the mediation process and submit the complaint to hearings. If the complaint is not submitted to mediation or if no agreement is reached during the mediation process, hearings shall be held on the complaint. If, after notice and hearing, the Commission finds that a telecommunications carrier has violated this Section or a rule promulgated under this Section, the Commission may in its discretion do any one or more of the following:

(1) Require the violating telecommunications carrier to refund to the subscriber all fees and charges collected from the subscriber for services up to the time the subscriber receives written notice of the fact that the violating carrier is providing telecommunications service to the subscriber, including notice on the subscriber's bill. For unreasonable delays wherein telecommunications service is provided by an unauthorized carrier, the Commission may require the violating carrier to refund to the subscriber all fees and charges collected from the subscriber during the unreasonable delay. The Commission may order the remedial action outlined in this subsection only to the extent that the same remedial action is allowed pursuant to rules or regulations promulgated by the Federal Communications Commission.

(2) Require the violating telecommunications carrier to refund to the subscriber charges collected in excess of those that would have been charged by the subscriber's authorized telecommunications carrier.

(3) Require the violating telecommunications carrier to pay to the subscriber's authorized telecommunications carrier the amount the authorized telecommunications carrier would have collected for the telecommunications service. The Commission is authorized to reduce this payment by any amount already paid by the violating telecommunications carrier to the subscriber's authorized telecommunications carrier for those telecommunications services.

(4) Require the violating telecommunications carrier to pay a fine of up to $1,000 into the Public Utility Fund for each repeated and intentional violation of this Section.

(5) Issue a cease and desist order.

(6) For a pattern of violation of this Section or for intentionally violating a cease and desist order, revoke the violating telecommunications carrier's certificate of service authority.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-903)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-903. Authorization, verification or notification, and dispute resolution for covered product and service charges on the telephone bill.

(a) Definitions. As used in this Section:

(1) "Subscriber" means a telecommunications carrier's retail business customer served by not more than 20 lines or a retail residential customer.

(2) "Telecommunications carrier" has the meaning given in Section 13-202 of the Public Utilities Act and includes agents and employees of a telecommunications carrier, except that "telecommunications carrier" does not include a provider of commercial mobile radio services (as defined by 47 U.S.C. 332(d)(1)).

(b) Applicability of Section. This Section does not apply to:

(1) changes in a subscriber's local exchange telecommunications service or interexchange telecommunications service;

(2) message telecommunications charges that are initiated by dialing 1+, 0+, 0-, 1010XXX, or collect calls and charges for video services if the service provider has the necessary call detail record to establish the billing for the call or service; and

(3) telecommunications services available on a subscriber's line when the subscriber activates and pays for the services on a per use basis.

(c) Requirements for billing authorized charges. A telecommunications carrier shall meet all of the following requirements before submitting charges for any product or service to be billed on any subscriber's telephone bill:

(1) Inform the subscriber. The telecommunications carrier offering the product or service must thoroughly inform the subscriber of the product or service being offered, including all associated charges, and explicitly inform the subscriber that the associated charges for the product or service will appear on the subscriber's telephone bill.

(2) Obtain subscriber authorization. The subscriber must have clearly and explicitly consented to obtaining the product or service offered and to having the associated charges appear on the subscriber's telephone bill. The consent must be verified by the service provider in accordance with subsection (d) of this Section. A record of the consent must be maintained by the telecommunications carrier offering the product or service for at least 24 months immediately after the consent and verification were obtained.

(d) Verification or notification. Except in subscriber-initiated transactions with a certificated telecommunications carrier for which the telecommunications carrier has the appropriate documentation, the telecommunications carrier, after obtaining the subscriber's authorization in the required manner, shall either verify the authorization or notify the subscriber as follows:

(1) Independent third-party verification:

(A) Verification shall be obtained by an independent third party that:

(i) operates from a facility physically separate from that of the telecommunications carrier;

(ii) is not directly or indirectly managed, controlled, directed, or owned wholly or in part by the telecommunications carrier or the carrier's marketing agent; and

(iii) does not derive commissions or compensation based upon the number of sales confirmed.

(B) The third-party verification agent shall state, and shall obtain the subscriber's acknowledgment of, the following disclosures:

(i) the subscriber's name, address, and the telephone numbers of all telephone lines that will be charged for the product or service of the telecommunications carrier;

(ii) that the person speaking to the third party verification agent is in fact the subscriber;

(iii) that the subscriber wishes to purchase the product or service of the telecommunications carrier and is agreeing to do so;

(iv) that the subscriber understands that the charges for the product or service of the telecommunications carrier will appear on the subscriber's telephone bill; and

(v) the name and customer service telephone number of the telecommunications carrier.

(C) The telecommunications carrier shall retain, electronically or otherwise, proof of the verification of sales for a minimum of 24 months.

(2) Notification. Written notification shall be provided as follows:

(A) the telecommunications carrier shall mail a letter to the subscriber using first class mail, postage prepaid, no later than 10 days after initiation of the product or service;

(B) the letter shall be a separate document sent for the sole purpose of describing the product or service of the telecommunications carrier;

(C) the letter shall be printed with 10-point or larger type and clearly and conspicuously disclose the material terms and conditions of the offer of the telecommunications carrier, as described in paragraph (1) of subsection (c);

(D) the letter shall contain a toll-free telephone number the subscriber can call to cancel the product or service;

(E) the telecommunications carrier shall retain, electronically or otherwise, proof of written notification for a minimum of 24 months; and

(F) written notification can be provided via electronic mail if consumers are given the disclosures required by Section 101(c) of the Electronic Signatures in Global and National Commerce Act.

(e) Unauthorized charges.

(1) Responsibilities of the billing telecommunications carrier for unauthorized charges. If a subscriber's telephone bill is charged for any product or service without proper subscriber authorization and verification or notification of authorization in compliance with this Section, the telecommunications carrier that billed the subscriber, on its knowledge or notification of any unauthorized charge, shall promptly, but not later than 45 days after the date of the knowledge or notification of an unauthorized charge:

(A) notify the product or service provider to immediately cease charging the subscriber for the unauthorized product or service;

(B) remove the unauthorized charge from the subscriber's bill; and

(C) refund or credit to the subscriber all money that the subscriber has paid for any unauthorized charge.

(f) The Commission shall promulgate any rules necessary to ensure that subscribers are not billed on the telephone bill for products or services in a manner not in compliance with this Section. The rules promulgated under this Section shall comport with the rules, if any, promulgated by the Attorney General pursuant to the Consumer Fraud and Deceptive Business Practices Act and with any rules promulgated by the Federal Communications Commission or Federal Trade Commission.

(g) Complaints may be filed with the Commission under this Section by a subscriber who has been billed on the telephone bill for products or services not in compliance with this Section or by the Commission on its own motion. Upon filing of the complaint, the parties may mutually agree to submit the complaint to the Commission's established mediation process. Remedies in the mediation process may include, but shall not be limited to, the remedies set forth in paragraphs (1) through (4) of this subsection. In its discretion, the Commission may deny the availability of the mediation process and submit the complaint to hearings. If the complaint is not submitted to mediation or if no agreement is reached during the mediation process, hearings shall be held on the complaint pursuant to Article X of this Act. If after notice and hearing, the Commission finds that a telecommunications carrier has violated this Section or a rule promulgated under this Section, the Commission may in its discretion order any one or more of the following:

(1) Require the violating telecommunications carrier to pay a fine of up to $1,000 into the Public Utility Fund for each repeated and intentional violation of this Section.

(2) Require the violating carrier to refund or cancel all charges for products or services not billed in compliance with this Section.

(3) Issue a cease and desist order.

(4) For a pattern of violation of this Section or for intentionally violating a cease and desist order, revoke the violating telecommunications carrier's certificate of service authority.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-904)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-904. Continuation of Article; validation.

(a) The General Assembly finds and declares that this amendatory Act of the 100th General Assembly manifests the intention of the General Assembly to extend the repeal of this Article and have this Article continue in effect until December 31, 2020.

(b) This Article shall be deemed to have been in continuous effect since July 1, 2017 and it shall continue to be in effect henceforward until it is otherwise lawfully repealed. All previously enacted amendments to this Article taking effect on or after July 1, 2017, are hereby validated. All actions taken in reliance on or under this Article by the Illinois Commerce Commission or any other person or entity are hereby validated.

(c) In order to ensure the continuing effectiveness of this Article, it is set forth in full and reenacted by this amendatory Act of the 100th General Assembly. Striking and underscoring are used only to show changes being made to the base text. This reenactment is intended as a continuation of this Article. It is not intended to supersede any amendment to this Article that is enacted by the 100th General Assembly.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/13-1200)

(Section scheduled to be repealed on January 1, 2030)

Sec. 13-1200. Repealer. This Article is repealed January 1, 2030.

(Source: P.A. 102-9, eff. 6-3-21; 103-601, eff. 7-1-24.)

(220 ILCS 5/Art. XIV heading) ARTICLE XIV. LOCAL TRANSIT COMMISSIONS

(220 ILCS 5/14-101) (from Ch. 111 2/3, par. 14-101)

Sec. 14-101. Whenever the city council of any city in this state shall pass and there shall become operative and effective an ordinance granting consent, permission and authority for the establishment, maintenance and operation of a comprehensive unified local transportation system, the major portion of which is or is to be located within or the major portion of the service of which is or is to be supplied to the inhabitants of such city, and which system is used or to be used chiefly for the transportation of persons, there shall be created and established a local transit commission as and for the purposes hereinafter provided.

Such local transit commission shall be designated "Transit Commission" preceded by the name of such city.

The term "transit commission" as hereinafter used in this Article means the local transit commission created and established pursuant to the provisions of this Article.

The term "city" as hereinafter used in this Article means any city establishing a local transit commission pursuant to the provisions of this Article.

The term "comprehensive unified local transportation system" as used in this Article means a transportation system comprising all of the street railways and also all of the local railroads the major portions of which are within the city (provided there are such local railroads in such city) and may also comprise public utility motor vehicle lines and/or any other local public utility transportation facilities, the major portions of which are within the city.

The term "local railroads" as herein used means railroads used chiefly for local passenger transportation and does not include a railroad constituting or used as part of a steam trunk line railroad system operated as a common carrier of freight and passengers.

The transit commission shall consist of three members to be appointed by the mayor by and with the advice and consent of the city council of the city, one of which members shall be designated chairman of the commission.

Immediately upon appointment the members of the commission shall respectively take and subscribe to the constitutional oath of office. Each member of the commission shall before entering upon the duties of his office give bond with a surety or sureties approved by the city council of the city in the sum of $25,000.00 conditioned upon the faithful performance of his duties as such member.

Upon the qualification of the members of the commission as herein provided, the commission shall be deemed created and established for all of the purposes of this Article, and the fact of such creation and establishment shall by the Commission be certified to the Governor of the State of Illinois and to the Illinois Commerce Commission.

(Source: P.A. 84-617.)

(220 ILCS 5/14-102) (from Ch. 111 2/3, par. 14-102)

Sec. 14-102. Terms of office, vacancies, restrictions, and removals.

Terms of office. The first members of the transit commission shall be appointed for two, three, and four year terms respectively. The term of office of each member thereafter appointed shall be four years.

Vacancies. Any vacancy in the membership of the transit commission occurring by reason of the death, resignation, disqualification, removal, or inability or refusal to act of any of the members of such transit commission shall be filled by appointment by the mayor by and with the advice and consent of the city council of the city.

Restrictions and removals. Each member of the transit commission shall devote all time necessary to perform properly and adequately the duties of his office, and shall hold no other office or position of profit, or engage in any other business, employment, or vocation to the detriment or neglect of such duties.

No person holding stocks or bonds in any corporation subject to the jurisdiction of the transit commission, or who is in any other manner directly or indirectly pecuniarily interested in any such corporation, shall be appointed as a member of the transit commission or shall be appointed or employed by the transit commission.

No member of the transit commission or any officer or employee of the transit commission shall voluntarily become so interested and if he shall become so interested otherwise than voluntarily he shall within a reasonable time divest himself of such interest.

No member of the transit commission or any officer or employee of the transit commission shall solicit or accept any gift, gratuity, emolument, or employment from any corporation subject to the jurisdiction of the transit commission or from any officer, agent, or employee thereof; nor solicit, request, or recommend directly or indirectly, to any such corporation or to any officer, agent, or employee thereof, the appointment or employment of any person by any such corporation to any office or position. And no such corporation or any officer, agent, or employee thereof, shall offer to any member of the transit commission or any officer or employee of the transit commission any gift, gratuity, emolument, or employment.

Violation of any of the provisions of this paragraph by any member, officer, or employee of the transit commission shall be ground for his removal from the office or employment held by him.

No member of the transit commission shall be removed from office during the term for which he shall be appointed except upon written charges made and sustained, as hereinafter provided for violation of any of the provisions of this paragraph, or for malfeasance, misfeasance, or nonfeasance in the discharge of the duties of his office.

Such charges shall be preferred by the mayor in writing to the city council of the city, or by resolution of the city council of the city and shall be investigated by a committee designated by the city council, which shall afford full opportunity to the commissioner complained of to appear and be heard in his own defense and to be represented by counsel.

The finding or decision of such committee shall be reported by it to the city council. In case such finding or decision shall sustain the charges and shall be approved by a vote of two-thirds of all of the members of the city council, the mayor of the city shall issue a declaration removing such commissioner from office and the vacancy thus created shall be filled as in this Section provided.

(Source: P.A. 103-154, eff. 6-30-23.)

(220 ILCS 5/14-103) (from Ch. 111 2/3, par. 14-103)

Sec. 14-103. Offices, employees and supplies, salaries.

Offices. The transit commission shall establish and maintain an office in the city hall of the city or at such other place as the city council of the city shall from time to time authorize or provide.

Such office shall be open for business between the hours of nine o'clock A. M. and five o'clock P. M. of each week day except holidays, except on Saturdays the hours shall be from nine o'clock A. M. to twelve o'clock noon.

Employees and supplies. The transit commission shall have power to appoint a secretary, and to employ such accountants, engineers, experts, inspectors, clerks, and other employees and fix their compensation, and to purchase such furniture, stationery, and other supplies and materials, as are reasonably necessary to enable it properly to perform its duties and exercise its powers.

The secretary and such other employees as the transit commission may require shall give bond in such amount and with such security as the transit commission may prescribe.

Salaries and expenses. Each of the members of the transit commission shall receive such annual salary as shall be fixed by the city council of the city.

The salary of any member shall not be reduced during his term of office.

The city council of the city shall have power to provide for the payment of the salaries of all members and the expenses of the transit commission.

(Source: P.A. 103-154, eff. 6-30-23.)

(220 ILCS 5/14-104) (from Ch. 111 2/3, par. 14-104)

Sec. 14-104. Rules and regulations, meetings, seal and authentication of records, etc.

Rules and regulations. Consistent with the provisions of this Article, the transit commission may adopt such rules and regulations and may alter and amend the same as it shall deem advisable relative to the calling, holding, and conduct of its meetings, the transaction of its business, the regulation and control of its agents and employees, the filing of complaints and petitions and the service of notices thereof and the conduct of hearings thereon, and the performance in general of its duties and powers hereunder.

Meetings. For the purpose of receiving, considering, and acting upon any complaints or applications which may be presented to it or for the purpose of conducting investigations or hearings on its own motion the transit commission shall hold a regular meeting at least once a week except in the months of July and August in each year. In addition to such other meetings of the transit commission as may be held, called or provided for by the rules and regulations of the transit commission, the Chairman shall call a meeting of the transit commission at any time upon the request of the mayor or city council of the city.

Quorum and Majority Rule. Two members of the transit commission shall constitute a quorum to transact business and no vacancy shall impair the right of the remaining commissioners to exercise all the powers of the transit commission; and every finding, order, decision, rule, regulation, or requirement of the transit commission approved by at least two members thereof shall be deemed to be the finding, order, decision, rule, regulation, or requirement of the transit commission.

Seal, Authentication of records, etc. The transit commission may adopt, keep, and use a common seal, of which judicial notice shall be taken in all courts of this State. Any process, notice, or other instrument which the transit commission may be authorized by law to issue shall be deemed sufficient if signed by the secretary of the transit commission and authenticated by such seal. All acts, orders, decisions, rules, and records of the transit commission, and all reports, schedules, and documents filed with the transit commission may be proved in any court in this State by a copy thereof certified by the secretary under the seal of the transit commission.

(Source: P.A. 103-154, eff. 6-30-23.)

(220 ILCS 5/14-105) (from Ch. 111 2/3, par. 14-105)

Sec. 14-105. Powers and duties. The jurisdiction, powers, and duties of the transit commission shall extend to:

(a) the comprehensive unified local transportation system for which a permit is granted as mentioned in the foregoing Section 14-101 of this Article including any and every part of such system extending or which may be extended into adjacent or suburban territory within this state lying outside of the city not more than 30 miles distant from the nearest point marking the corporate limits of the city;

(b) all other local public utility transportation facilities owned or operated or to be owned or operated mainly in the transportation of persons the major portion of which facilities are located or to be located within, or the major portion of the service of which is or is to be supplied to the inhabitants of the city, including such part or parts of any of said facilities extending or which may be extended into adjacent and suburban territory within this state lying outside of the city within 30 miles distant from the nearest point marking the corporate limits of the city; but not including any railroad located or to be located in the city constituting or used as part of a steam trunk line railroad system, operated as a common carrier of freight and passengers;

(c) every corporation that now or hereafter may or may be authorized to own, control, operate, or manage the comprehensive unified local transportation system or any of the other local transportation facilities mentioned in the preceding paragraphs (a) and (b) of this Section.

With respect to said comprehensive unified local transportation system and said other local transportation facilities and those owning and/or operating or authorized to own and/or operate the same as aforesaid, the transit commission shall have the same regulatory and supervisory powers and duties as are conferred and imposed upon the Illinois Commerce Commission by the provisions of this Act.

Provided, however, that the initial acquisition, consolidation, unification, or merger of the properties for the establishment of and to comprise said comprehensive unified local transportation system and the issuance of bonds, stocks, or other securities therefor or in connection therewith, shall be within and subject to the jurisdiction and control of the Illinois Commerce Commission with respect to any consent, permission, approval, authority, or certificate for such acquisition, consolidation, or merger of said properties including any certificate of convenience and necessity, and the issuance of such securities required by the provisions of this Act.

(Source: P.A. 84-617.)

(220 ILCS 5/14-106) (from Ch. 111 2/3, par. 14-106)

Sec. 14-106. Proceedings before the Commission and in the courts. The provisions of Article X, Sections 4-201 through 4-205, Sections 5-201 through 5-203, and Section 9-252 of this Act, except as herein otherwise provided, shall apply to and govern the proceedings by or before the transit commission, appeals from the rules, regulations, orders, or decisions of the transit commission, and actions for the enforcement of rules, regulations, orders, or decisions of the transit commission or to recover penalties for violation thereof or of the provisions of this Article XIV.

(Source: P.A. 84-617.)

(220 ILCS 5/14-107) (from Ch. 111 2/3, par. 14-107)

Sec. 14-107. Powers of supervision, etc. Except as otherwise provided in this Article the transit commission shall have general supervision of the corporations owning or operating the comprehensive unified local transportation system or any of the other local transportation facilities mentioned in the foregoing Section 14-105. It shall inquire into and keep itself informed as to the general condition of such corporations their franchises, capitalization, rates and charges, the manner in which their properties are managed and operated with respect to adequacy of service, and as to compliance with the applicable provisions of this Act, with the orders of the transit commission, and with the requirements, terms, and conditions of any ordinance grant, permit or franchise.

The corporations subject to the jurisdiction of the transit commission shall furnish to the commission all information required by it to carry into effect the provisions of this Article.

Whenever required by the transit commission such corporations shall deliver to the commission all maps, profiles, reports, documents, books, accounts, papers and records in their possession in any way relating to their property or affecting their business, and inventories of their property, in such form as the commission may direct, or verified copies of all or any of the same.

(Source: P.A. 84-617.)

(220 ILCS 5/14-108) (from Ch. 111 2/3, par. 14-108)

Sec. 14-108. Transit Commission's powers to be regulatory. The powers and duties conferred and imposed upon the transit commission are to be taken and deemed powers and duties of reasonable and lawful public service regulation as distinguished from managerial powers or functions.

(Source: P.A. 84-617.)

(220 ILCS 5/14-109) (from Ch. 111 2/3, par. 14-109)

Sec. 14-109. Transit Commission to supersede Illinois Commerce Commission. As concerns the comprehensive unified local transportation system and other local transportation facilities mentioned in the foregoing Section 14-105 and the corporations, owning and/or operating or authorized to own and/or operate the same, the transit commission shall supersede the Illinois Commerce Commission created by this Act and the Illinois Commerce Commission shall have no jurisdiction over such system, facilities or corporations, except as otherwise provided in this Article.

(Source: P.A. 84-617.)

(220 ILCS 5/14-110) (from Ch. 111 2/3, par. 14-110)

Sec. 14-110. Saving provisions. The creation of a transit commission under this Article shall not affect pending actions or proceedings instituted in any court under the provisions of this Act by or against any public utility corporation owning or operating local transportation facilities which are subject to the jurisdiction of such transit commission as in this Article provided.

Any investigation, hearing, or proceeding instituted or conducted by the Illinois Commerce Commission under the provisions of this Act against or concerning any such public utility corporation and pending and undetermined at the time of the creation of such transit commission shall be conducted and continued to final determination by such transit commission except as herein otherwise provided.

All orders, decisions, rules, or regulations heretofore made, issued, or promulgated by the Illinois Commerce Commission under the provisions of this Act relating to or affecting any such public utility corporation, shall continue in force; but such transit commission shall have all powers with respect to such orders, decisions, rules, or regulations, the same as if made, issued, or promulgated by such transit commission under the provisions of this Article.

(Source: P.A. 84-617.)

(220 ILCS 5/Art. XV heading) ARTICLE XV. COMMON CARRIERS BY PIPELINE

(220 ILCS 5/15-100)

Sec. 15-100. Short Title. This Article may be cited as the Common Carrier by Pipeline Law.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-101)

Sec. 15-101. Application of Article. Except to the extent modified or supplemented by the specific provisions of this Article, Articles I to IV, Sections 5-101, 5-201, 5-202, 5-203, 8-101, 8-503, 8-509, 9-221, 9-222, 9-222.1, 9-222.2, and 9-250, and Article X are fully and equally applicable to common carriers by pipeline, their rates and services, and the regulation thereof.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-102)

Sec. 15-102. Application to natural gas and water common carriers by pipeline. Article VII of the Public Utilities Act is fully and equally applicable to transactions between common carriers of natural gas and water by pipeline and affiliated public utilities.

(Source: P.A. 89-42, eff. 1-1-96; 89-573, eff. 7-30-96.)

(220 ILCS 5/15-103)

Sec. 15-103. Application of carbon dioxide pipelines. This Article does not apply to a new carbon dioxide pipeline as defined in Section 10 of the Carbon Dioxide Transportation and Sequestration Act.

(Source: P.A. 103-651, eff. 7-18-24.)

(220 ILCS 5/15-201)

Sec. 15-201. Definitions. In this Law:

"Common carrier by pipeline" means (1) a person or corporation that owns, controls, operates, or manages, within this State, directly or indirectly, equipment, facilities, or other property, or a franchise, permit, license, or right, used or to be used in connection with the conveyance of gas or any liquid other than water for the general public in common carriage by pipeline, or (2) a person or corporation that owns and operates within this State any equipment, facilities, or other property, or any franchise, permit, license, or right, used or to be used in connection with the conveyance of water drawn from Lake Michigan for the general public in common carriage by pipeline. A gas public utility that provides local distribution services is not a common carrier by pipeline, irrespective of whether the public utility transports customer-owned gas or gas owned by a third party to some of its customers. A water public utility that provides local distribution services is not a common carrier by pipeline. A unit of local government is not a common carrier by pipeline. In addition, "common carrier by pipeline" does not include common carriers by pipeline that are owned and operated by any political subdivision, public institution of higher education or municipal corporation of this State, or common carriers by pipeline that are owned by such political subdivision, public institution of higher education, or municipal corporation and operated by any of its lessees or operating agents.

(Source: P.A. 89-42, eff. 1-1-96; 89-573, eff. 7-30-96; 89-713, eff. 2-21-97.)

(220 ILCS 5/15-301)

Sec. 15-301. Records and accounts.

(a) Each common carrier by pipeline shall:

(1) Keep written accounts and records of its revenues, expenses, contracts, and other activities subject to regulation under this Act in accordance with regulations prescribed by the Commission;

(2) Maintain, for a period of 3 years, copies of all accounts and records required by Commission regulations; and

(3) Make the accounts and records available for inspection, on request, by an authorized employee of the Commission.

(b) Accounts and records kept under this Section shall be kept at an office in the State of Illinois unless the Commission shall have authorized maintenance at a location outside of the State.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-401)

Sec. 15-401. Licensing.

(a) No person shall operate as a common carrier by pipeline unless the person possesses a certificate in good standing authorizing it to operate as a common carrier by pipeline. No person shall begin or continue construction of a pipeline or other facility, other than the repair or replacement of an existing pipeline or facility, for use in operations as a common carrier by pipeline unless the person possesses a certificate in good standing.

(b) Requirements for issuance. The Commission, after a hearing, shall grant an application for a certificate authorizing operations as a common carrier by pipeline, in whole or in part, to the extent that it finds that the application was properly filed; a public need for the service exists; the applicant is fit, willing, and able to provide the service in compliance with this Act, Commission regulations, and orders; and the public convenience and necessity requires issuance of the certificate. Evidence encompassing any of the factors described in items (1) through (9) of this subsection (b) that is submitted by the applicant, any other party, or the Commission's staff shall also be considered by the Commission in determining whether a public need for the service exists under either current or expected conditions. The changes in this subsection (b) are intended to be confirmatory of existing law.

In its determination of public convenience and necessity for a proposed pipeline or facility designed or intended to transport crude oil and any alternate locations for such proposed pipeline or facility, the Commission shall consider, but not be limited to, the following:

(1) any evidence presented by the Illinois Environmental Protection Agency regarding the environmental impact of the proposed pipeline or other facility;

(2) any evidence presented by the Illinois Department of Transportation regarding the impact of the proposed pipeline or facility on traffic safety, road construction, or other transportation issues;

(3) any evidence presented by the Department of Natural Resources regarding the impact of the proposed pipeline or facility on any conservation areas, forest preserves, wildlife preserves, wetlands, or any other natural resource;

(4) any evidence of the effect of the pipeline upon the economy, infrastructure, and public safety presented by local governmental units that will be affected by the proposed pipeline or facility;

(5) any evidence of the effect of the pipeline upon property values presented by property owners who will be affected by the proposed pipeline or facility, provided that the Commission need not hear evidence as to the actual valuation of property such as that as would be presented to and determined by the courts under the Eminent Domain Act;

(6) any evidence presented by the Department of Commerce and Economic Opportunity regarding the current and future local, State-wide, or regional economic effect, direct or indirect, of the proposed pipeline or facility including, but not limited to, property values, employment rates, and residential and business development;

(7) any evidence addressing the factors described in items (1) through (9) of this subsection (b) or other relevant factors that is presented by any other State agency, the applicant, a party, or other entity that participates in the proceeding, including evidence presented by the Commission's staff;

(8) any evidence presented by a State agency or unit of State or local government as to the current and future national, State-wide, or regional economic effects of the proposed pipeline, direct or indirect, as they affect residents or businesses in Illinois, including, but not limited to, such impacts as the ability of manufacturers in Illinois to meet public demand for related services and products and to compete in the national and regional economies, improved access of suppliers to regional and national shipping grids, the ability of the State to access funds made available for energy infrastructure by the federal government, mitigation of foreseeable spikes in price affecting Illinois residents or businesses due to sudden changes in supply or transportation capacity, and the likelihood that the proposed construction will substantially encourage related investment in the State's energy infrastructure and the creation of energy related jobs; and

(9) any evidence presented by any State or federal governmental entity as to how the proposed pipeline or facility will affect the security, stability, and reliability of energy in the State or in the region.

In its written order, the Commission shall address all of the evidence presented, and if the order is contrary to any of the evidence, the Commission shall state the reasons for its determination with regard to that evidence.

(c) An application filed pursuant to this Section may request either that the Commission review and approve a specific route for a pipeline, or that the Commission review and approve a project route width that identifies the areas in which the pipeline would be located, with such width ranging from the minimum width required for a pipeline right-of-way up to 500 feet in width. The purpose for allowing the option of review and approval of a project route width is to provide increased flexibility during the construction process to accommodate specific landowner requests, avoid environmentally sensitive areas, or address special environmental permitting requirements.

(d) A common carrier by pipeline may request any other approvals as may be needed from the Commission for completion of the pipeline under Article VIII or any other Article or Section of this Act at the same time, and as part of the same application, as its request for a certificate of good standing under this Section. The Commission's rules shall ensure that notice of such a consolidated application is provided within 30 days after filing to the landowners along a proposed project route, or to the potentially affected landowners within a proposed project route width, using the notification procedures set forth in the Commission's rules. If a consolidated application is submitted, then the requests shall be heard on a consolidated basis and a decision on all issues shall be entered within the time frames stated in subsection (e) of this Section. In such a consolidated proceeding, the Commission may consider evidence relating to the same factors identified in items (1) through (9) of subsection (b) of this Section in granting authority under Section 8-503 of this Act. If the Commission grants approval of a project route width as opposed to a specific project route, then the common carrier by pipeline must, as it finalizes the actual pipeline alignment within the project route width, file its final list of affected landowners with the Commission at least 14 days in advance of beginning construction on any tract within the project route width and also provide the Commission with at least 14 days notice before filing a complaint for eminent domain in the circuit court with regard to any tract within the project route width.

(e) The Commission shall make its determination on any application filed pursuant to this Section and issue its final order within one year after the date that the application is filed unless an extension is granted as provided in this subsection (e). The Commission may extend the one-year time period for issuing a final order on an application filed pursuant to this Section up to an additional 6 months if it finds, following the filing of initial testimony by the parties to the proceeding, that due to the number of affected landowners and other parties in the proceeding and the complexity of the contested issues before it, additional time is needed to ensure a complete review of the evidence. If an extension is granted, then the schedule for the proceeding shall not be further extended beyond this 6-month period, and the Commission shall issue its final order within the 6-month extension period. The Commission shall also have the power to establish an expedited schedule for making its determination on an application filed pursuant to this Section in less than one year if it finds that the public interest requires the setting of such an expedited schedule.

(f) Within 6 months after the Commission's entry of an order approving either a specific route or a project route width under this Section, the common carrier by pipeline that receives such order may file supplemental applications for minor route deviations outside the approved project route width, allowing for additions or changes to the approved route to address environmental concerns encountered during construction or to accommodate landowner requests. Notice of a supplemental application shall be provided to any State agency that appeared in the original proceeding or immediately affected landowner at the time such supplemental application is filed. The route deviations shall be approved by the Commission within 45 days, unless a written objection is filed to the supplemental application within 20 days after the date such supplemental application is filed. Hearings on any such supplemental application shall be limited to the reasonableness of the specific variance proposed, and the issues of public need or public convenience or necessity for the project or fitness of the applicant shall not be reopened in the supplemental proceeding.

(g) The rules of the Commission may include additional options for expediting the issuance of permits and certificates under this Section. Such rules may provide that, in the event that an applicant elects to use an option provided for in such rules; (1) the applicant must request the use of the expedited process at the time of filing its application for a license or permit with the Commission; (2) the Commission may engage experts and procure additional administrative resources that are reasonably necessary for implementing the expedited process; and (3) the applicant must bear any additional costs incurred by the Commission as a result of the applicant's use of such expedited process.

(h) Duties and obligations of common carriers by pipeline. Each common carrier by pipeline shall provide adequate service to the public at reasonable rates and without discrimination.

(Source: P.A. 97-405, eff. 8-16-11.)

(220 ILCS 5/15-501)

Sec. 15-501. Published rates. No common carrier by pipeline shall render service until the carrier has in effect a tariff or schedule of rates applicable to service in compliance with this Act. No carrier shall render service under a license issued by the Commission if the Commission has suspended or cancelled the tariff or schedule of rates previously in effect and applicable to the service, or if the tariff or schedule is, by action of a party thereto or by its own terms, no longer effective.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-502)

Sec. 15-502. Effective dates of new or amended rates. The Commission shall prescribe the periods of notice that must elapse between the filing of a proposed rate and its proposed effective date. The Commission shall not prescribe a notice period greater than 45 days.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-503)

Sec. 15-503. (a) General requirement of filing, publication, and posting. Each common carrier by pipeline shall file, publish, and make available for public inspection its current tariffs. Copies of the tariffs shall be provided by the carrier to members of the public on request at a reasonable cost.

(b) Tariff and schedule specifications. Tariffs and schedules filed in accordance with this subsection shall be in the form and contain the information as the Commission may specify. The Commission may, by special permission for good cause shown, grant permission to deviate from its tariff and schedule regulations.

(c) Rejection of tariffs and schedules. The Commission may, at any time prior to the effective date of a tariff or schedule, reject or suspend a tariff or schedule that does not conform to its specifications or that on its face is in violation of this Act, Commission regulations, or orders.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-504)

Sec. 15-504. Rate proceedings.

(a) Initiation of proceedings. The Commission may initiate a proceeding to investigate or prescribe tariffs or schedules on its own motion or complaint.

(b) Suspension of tariffs. The Commission may suspend a tariff, in whole or in part, during the pendency of a proceeding to consider the reasonableness of the tariff, whether it is discriminatory, or whether it otherwise violates provisions of this Article, Commission regulations, or orders, provided the order of suspension is issued prior to the effective date of the tariff. The suspension shall remain in effect for 11 months unless the Commission order provides for a shorter period of suspension. At the end of the statutory suspension period, the suspension may be extended by agreement of the parties; otherwise, the tariff shall go into effect.

(c) Burden of proof in investigation proceedings. The burden of proof in an investigation proceeding shall be on the proponent of the rate.

(d) Prescription of tariffs and schedules. The Commission may prescribe tariffs if it has determined that a tariff published by a carrier is unreasonable, discriminatory, or otherwise in violation of this Article, Commission regulations, or orders. The Commission may prescribe schedules if it has determined, after a hearing, that a schedule filed by a carrier is in violation of this Article, Commission regulations, or orders.

(e) Relief. The Commission may, if it finds a tariff or schedule is in violation of this Article, its regulations, or orders, or finds rates or provisions in a tariff unjust, unreasonable, or discriminatory, direct the carrier to:

(1) Publish and file a supplement cancelling the tariff or file notice of cancellation of the schedule, in whole or in part;

(2) Publish and file a new tariff or file a new schedule containing rates and provisions prescribed by the Commission; and

(3) Repay any overcharges or collect any undercharges, and pay reparations.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-505)

Sec. 15-505. Ratemaking standards. Rates for common carrier by pipeline service must be just, reasonable, and not discriminatory. The Commission shall, in exercising its ratemaking powers, consider, among other factors, the inherent advantages of transportation by common carrier pipeline, the public need for and interest in adequate and efficient transportation service, at rates consistent with provision of the service, and the revenue needs of carriers under honest, economical, and efficient management. The Commission shall not, in exercising its ratemaking powers, consider the value of any operating authority held by a carrier, or the value of goodwill or earning power connected with operations of the carrier.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-506)

Sec. 15-506. Charges to conform to tariffs or schedules and orders of the Commission.

(a) Overcharges and undercharges prohibited. No common carrier by pipeline shall offer, advertise, charge, demand, collect, or receive, in any manner, a greater, lesser, or different compensation for transportation or service in connection therewith than the rates and charges specified in tariffs or schedules on file with the Commission and in effect at the time the transportation or other service is rendered. No carrier shall offer, advertise, charge, demand, collect, or receive any compensation for transportation or other service rendered in connection therewith if there is not in effect at the time a lawfully applicable tariff or schedule. No carrier shall refund or remit, in any manner, or by any device, whether directly or indirectly, or through an agent or otherwise, other than or under Commission order, a portion of the rates or charges specified in tariffs or schedules on file with the Commission and in effect at the time. No carrier shall extend a discount, value, privilege, or facility for transportation or service rendered in connection therewith, except as specified in tariffs or schedules on file with the Commission and in effect at the time.

(b) Repayment of overcharges, collection of undercharges and reparations.

(1) Repayment of overcharges and payment of reparations. The Commission may order a common carrier by pipeline to pay to one or more shippers the amount of compensation the carrier received that was greater than the rates and charges specified in tariffs or schedules in effect at the time the carrier rendered the transportation or other service in connection therewith. The Commission may likewise order a common carrier by pipeline to pay to one or more shippers the amount of compensation the carrier received that was greater than reasonable rates and charges as determined by the Commission.

(2) Collection of undercharges. The Commission may order a common carrier by pipeline to make all reasonable efforts to collect from one or more shippers the difference between amounts collected and the amount of compensation specified in tariffs or schedules in effect at the time the transportation or other service in connection therewith was rendered.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-507)

Sec. 15-507. Joint rates and routes.

(a) Establishment by carriers. Two or more common carriers by pipeline may establish through routes and joint rates, provided that the rates, divisions, and practices relating thereto are just, reasonable, and not discriminatory.

(b) Establishment by the Commission. The Commission may, on its own motion, petition, or complaint, where 2 or more carriers by pipeline have failed to establish through routes, joint rates, divisions, and practices relating thereto, establish such routes, rates, divisions, and practices. The Commission shall take this action only after notice and a hearing to consider whether the proposed routes, rates, divisions, and practices are just, reasonable, and not discriminatory, whether a carrier has a reasonable objection to establishment of the routes, rates, divisions, and practices, and whether the objections can be satisfied by imposing reasonable terms and conditions on the application of the routes, rates, divisions, and practices.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-508)

Sec. 15-508. Statute of limitations for charges.

(a) Collection actions. Actions to collect charges under lawfully applicable rates must be instituted within 3 years after rendition of the service.

(b) Reparations or overcharge proceedings. Petitions seeking reparations or repayment of overcharges must be filed with the Commission within 3 years after rendition of the service, and an action seeking judicial enforcement of a Commission order awarding reparations must be instituted within one year after issuance of such order. Where an action seeking judicial review of a Commission order awarding reparations is filed, the time preceding final adjudication of the action shall be excluded in computing the time for instituting the action seeking judicial enforcement of the Commission order.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-509)

Sec. 15-509. Rules. The Commission may adopt standards and procedures to ensure that the rates of common carriers by pipeline are reasonable and not discriminatory. These regulations may provide for prescription of rates, or for publications subject to investigation and suspension, and may establish special standards and procedures for other matters necessary to effectuate the purposes of this Article.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-601)

Sec. 15-601. Safety regulation. Each common carrier by pipeline shall construct, maintain, and operate all of its pipelines, related facilities, and equipment in this State in a manner that poses no undue risk to its employees, customers, or the public. The obligation of the carrier shall include the construction, maintenance, and operation of safety devices or structures, the revision of practices effecting safety, and other acts necessary to ensure the safety of its employees, customers, and the public. The Commission may, by reference to federal safety regulations or otherwise, adopt reasonable regulations governing the construction, maintenance, and operations of pipelines, related facilities, and equipment to ensure the safety of pipeline employees, customers, and the public.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/15-701)

Sec. 15-701. Grandfather provision. All certificates of public convenience and necessity for common carrier by pipeline, tariffs and schedules, and findings, orders, decisions, rules, and regulations, issued under the repealed provisions of the Illinois Commercial Transportation Law, and not subject to judicial review as of the effective date of this amendatory Act of 1995, shall continue in full force and effect as if adopted, issued, established, or recognized under the Public Utilities Act.

(Source: P.A. 89-42, eff. 1-1-96.)

(220 ILCS 5/Art. XVI heading) ARTICLE XVI. ELECTRIC SERVICE CUSTOMER CHOICE AND RATE RELIEF LAW OF 1997

(220 ILCS 5/16-101)

Sec. 16-101. Short title and applicability.

(a) This Article may be cited as the Electric Service Customer Choice and Rate Relief Law of 1997 and shall apply to electric utilities and alternative retail electric suppliers as defined in this Article. Except to the extent modified or supplemented by the provisions of this Article, or where the context clearly renders such provisions inapplicable, the other Articles of the Public Utilities Act pertaining to public utilities, public utility rates and services and the regulation thereof, are fully and equally applicable to the tariffed services electric utilities provide.

(b) The provisions of subsections (a) through (h) of Section 16-111 of this Act shall not be applicable to any electric utility which elects to file biennial rate proceedings before the Commission in the years 1998, 2000 and 2002. An electric utility electing this option shall do so by filing a notice of such election with the Commission within 60 days after the effective date of this amendatory Act of 1997, or its right to make such election shall be irrevocably waived. An electric utility electing the option specified in this paragraph shall file its rate proceeding with the Commission no later than August 1 of the years 1998, 2000, and 2002. The electric utility's filing shall comply with all requirements of 83 Illinois Administrative Code Parts 255 and 285 as though the electric utility were filing for an increase in its rates, without regard to whether such filing would produce an increase, a decrease or no change in the electric utility's rates and the Commission shall review the electric utility's filing and shall issue its order in accordance with the provisions of Section 9-201 of this Act.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-101A)

Sec. 16-101A. Legislative findings.

(a) The citizens and businesses of the State of Illinois have been well-served by a comprehensive electrical utility system which has provided safe, reliable, and affordable service. The electrical utility system in the State of Illinois has historically been subject to State and federal regulation, aimed at assuring the citizens and businesses of the State of safe, reliable, and affordable service, while at the same time assuring the utility system of a return on its investment.

(b) Competitive forces are affecting the market for electricity as a result of recent federal regulatory and statutory changes and the activities of other states. Competition in the electric services market may create opportunities for new products and services for customers and lower costs for users of electricity. Long-standing regulatory relationships need to be altered to accommodate the competition that could fundamentally alter the structure of the electric services market.

(c) With the advent of increasing competition in this industry, the State has a continued interest in assuring that the safety, reliability, and affordability of electrical power is not sacrificed to competitive pressures, and to that end, intends to implement safeguards to assure that the industry continues to operate the electrical system in a manner that will serve the public's interest. Under the existing regulatory framework, the industry has been encouraged to undertake certain investments in its physical plant and personnel to enhance its efficient operation, the cost of which it has been permitted to pass on to consumers. The State has an interest in providing the existing utilities a reasonable opportunity to obtain a return on certain investments on which they depended in undertaking those commitments in the first instance while, at the same time, not permitting new entrants into the industry to take unreasonable advantage of the investments made by the formerly regulated industry.

(d) A competitive wholesale and retail market must benefit all Illinois citizens. The Illinois Commerce Commission should act to promote the development of an effectively competitive electricity market that operates efficiently and is equitable to all consumers. Consumer protections must be in place to ensure that all customers continue to receive safe, reliable, affordable, and environmentally safe electric service.

(e) All consumers must benefit in an equitable and timely fashion from the lower costs for electricity that result from retail and wholesale competition and receive sufficient information to make informed choices among suppliers and services. The use of renewable resources and energy efficiency resources should be encouraged in competitive markets.

(f) The efficiency of electric markets depends both upon the competitiveness of supply and upon the price-responsiveness of the demand for service. Therefore, to ensure the lowest total cost of service and to enhance the reliability of service, all classes of the electricity customers of electric utilities should have access to and be able to voluntarily use real-time pricing and other price-response and demand-response mechanisms.

(g) Including cost-effective renewable resources and demand-response resources in a diverse electricity supply portfolio will reduce long-term direct and indirect costs to consumers by decreasing environmental impacts and by avoiding or delaying the need for new generation, transmission, and distribution infrastructure. It serves the public interest to allow electric utilities to recover costs for reasonably and prudently incurred expenses for electricity generated by renewable resources and demand-response resources.

(h) Including electricity generated by clean coal facilities, as defined under Section 1-10 of the Illinois Power Agency Act, in a diverse electricity procurement portfolio will reduce the need to purchase, directly or indirectly, carbon dioxide emission credits and will decrease environmental impacts. It serves the public interest to allow electric utilities to recover costs for reasonably and prudently incurred expenses for sourcing electricity generated by clean coal facilities.

(Source: P.A. 94-977, eff. 6-30-06; 95-481, eff. 8-28-07; 95-1027, eff. 6-1-09.)

(220 ILCS 5/16-102)

Sec. 16-102. Definitions. For the purposes of this Article the following terms shall be defined as set forth in this Section.

"Alternative retail electric supplier" means every person, cooperative, corporation, municipal corporation, company, association, joint stock company or association, firm, partnership, individual, or other entity, their lessees, trustees, or receivers appointed by any court whatsoever, that offers electric power or energy for sale, lease or in exchange for other value received to one or more retail customers, or that engages in the delivery or furnishing of electric power or energy to such retail customers, and shall include, without limitation, resellers, aggregators and power marketers, but shall not include (i) electric utilities (or any agent of the electric utility to the extent the electric utility provides tariffed services to retail customers through that agent), (ii) any electric cooperative or municipal system as defined in Section 17-100 to the extent that the electric cooperative or municipal system is serving retail customers within any area in which it is or would be entitled to provide service under the law in effect immediately prior to the effective date of this amendatory Act of 1997, (iii) a public utility that is owned and operated by any public institution of higher education of this State, or a public utility that is owned by such public institution of higher education and operated by any of its lessees or operating agents, within any area in which it is or would be entitled to provide service under the law in effect immediately prior to the effective date of this amendatory Act of 1997, (iv) a retail customer to the extent that customer obtains its electric power and energy from that customer's own cogeneration or self-generation facilities, (v) an entity that owns, operates, sells, or arranges for the installation of a customer's own cogeneration or self-generation facilities, but only to the extent the entity is engaged in owning, selling or arranging for the installation of such facility, or operating the facility on behalf of such customer, provided however that any such third party owner or operator of a facility built after January 1, 1999, complies with the labor provisions of Section 16-128(a) as though such third party were an alternative retail electric supplier, or (vi) an industrial or manufacturing customer that owns its own distribution facilities, to the extent that the customer provides service from that distribution system to a third-party contractor located on the customer's premises that is integrally and predominantly engaged in the customer's industrial or manufacturing process; provided, that if the industrial or manufacturing customer has elected delivery services, the customer shall pay transition charges applicable to the electric power and energy consumed by the third-party contractor unless such charges are otherwise paid by the third party contractor, which shall be calculated based on the usage of, and the base rates or the contract rates applicable to, the third-party contractor in accordance with Section 16-102.

An entity that furnishes the service of charging electric vehicles does not and shall not be deemed to sell electricity and is not and shall not be deemed an alternative retail electric supplier, and is not subject to regulation as such under this Act notwithstanding the basis on which the service is provided or billed. If, however, the entity is otherwise deemed an alternative retail electric supplier under this Act, or is otherwise subject to regulation under this Act, then that entity is not exempt from and remains subject to the otherwise applicable provisions of this Act. The installation, maintenance, and repair of an electric vehicle charging station shall comply with the requirements of subsection (a) of Section 16-128 and Section 16-128A of this Act.

For purposes of this Section, the term "electric vehicles" has the meaning ascribed to that term in Section 10 of the Electric Vehicle Act.

"Base rates" means the rates for those tariffed services that the electric utility is required to offer pursuant to subsection (a) of Section 16-103 and that were identified in a rate order for collection of the electric utility's base rate revenue requirement, excluding (i) separate automatic rate adjustment riders then in effect, (ii) special or negotiated contract rates, (iii) delivery services tariffs filed pursuant to Section 16-108, (iv) real-time pricing, or (v) tariffs that were in effect prior to October 1, 1996 and that based charges for services on an index or average of other utilities' charges, but including (vi) any subsequent redesign of such rates for tariffed services that is authorized by the Commission after notice and hearing.

"Competitive service" includes (i) any service that has been declared to be competitive pursuant to Section 16-113 of this Act, (ii) contract service, and (iii) services, other than tariffed services, that are related to, but not necessary for, the provision of electric power and energy or delivery services.

"Contract service" means (1) services, including the provision of electric power and energy or other services, that are provided by mutual agreement between an electric utility and a retail customer that is located in the electric utility's service area, provided that, delivery services shall not be a contract service until such services are declared competitive pursuant to Section 16-113; and also means (2) the provision of electric power and energy by an electric utility to retail customers outside the electric utility's service area pursuant to Section 16-116. Provided, however, contract service does not include electric utility services provided pursuant to (i) contracts that retail customers are required to execute as a condition of receiving tariffed services, or (ii) special or negotiated rate contracts for electric utility services that were entered into between an electric utility and a retail customer prior to the effective date of this amendatory Act of 1997 and filed with the Commission.

"Delivery services" means those services provided by the electric utility that are necessary in order for the transmission and distribution systems to function so that retail customers located in the electric utility's service area can receive electric power and energy from suppliers other than the electric utility, and shall include, without limitation, standard metering and billing services.

"Electric utility" means a public utility, as defined in Section 3-105 of this Act, that has a franchise, license, permit or right to furnish or sell electricity to retail customers within a service area.

"Mandatory transition period" means the period from the effective date of this amendatory Act of 1997 through January 1, 2007.

"Municipal system" shall have the meaning set forth in Section 17-100.

"Real-time pricing" means tariffed retail charges for delivered electric power and energy that vary hour-to-hour and are determined from wholesale market prices using a methodology approved by the Illinois Commerce Commission.

"Retail customer" means a single entity using electric power or energy at a single premises and that (A) either (i) is receiving or is eligible to receive tariffed services from an electric utility, or (ii) that is served by a municipal system or electric cooperative within any area in which the municipal system or electric cooperative is or would be entitled to provide service under the law in effect immediately prior to the effective date of this amendatory Act of 1997, or (B) an entity which on the effective date of this Act was receiving electric service from a public utility and (i) was engaged in the practice of resale and redistribution of such electricity within a building prior to January 2, 1957, or (ii) was providing lighting services to tenants in a multi-occupancy building, but only to the extent such resale, redistribution or lighting service is authorized by the electric utility's tariffs that were on file with the Commission on the effective date of this Act.

"Service area" means (i) the geographic area within which an electric utility was lawfully entitled to provide electric power and energy to retail customers as of the effective date of this amendatory Act of 1997, and includes (ii) the location of any retail customer to which the electric utility was lawfully providing electric utility services on such effective date.

"Small commercial retail customer" means those nonresidential retail customers of an electric utility consuming 15,000 kilowatt-hours or less of electricity annually in its service area.

"Tariffed service" means services provided to retail customers by an electric utility as defined by its rates on file with the Commission pursuant to the provisions of Article IX of this Act, but shall not include competitive services.

"Transition charge" means a charge expressed in cents per kilowatt-hour that is calculated for a customer or class of customers as follows for each year in which an electric utility is entitled to recover transition charges as provided in Section 16-108:

(1) the amount of revenue that an electric utility would receive from the retail customer or customers if it were serving such customers' electric power and energy requirements as a tariffed service based on (A) all of the customers' actual usage during the 3 years ending 90 days prior to the date on which such customers were first eligible for delivery services pursuant to Section 16-104, and (B) on (i) the base rates in effect on October 1, 1996 (adjusted for the reductions required by subsection (b) of Section 16-111, for any reduction resulting from a rate decrease under Section 16-101(b), for any restatement of base rates made in conjunction with an elimination of the fuel adjustment clause pursuant to subsection (b), (d), or (f) of Section 9-220 and for any removal of decommissioning costs from base rates pursuant to Section 16-114) and any separate automatic rate adjustment riders (other than a decommissioning rate as defined in Section 16-114) under which the customers were receiving or, had they been customers, would have received electric power and energy from the electric utility during the year immediately preceding the date on which such customers were first eligible for delivery service pursuant to Section 16-104, or (ii) to the extent applicable, any contract rates, including contracts or rates for consolidated or aggregated billing, under which such customers were receiving electric power and energy from the electric utility during such year;

(2) less the amount of revenue, other than revenue from transition charges and decommissioning rates, that the electric utility would receive from such retail customers for delivery services provided by the electric utility, assuming such customers were taking delivery services for all of their usage, based on the delivery services tariffs in effect during the year for which the transition charge is being calculated and on the usage identified in paragraph (1);

(3) less the market value for the electric power and energy that the electric utility would have used to supply all of such customers' electric power and energy requirements, as a tariffed service, based on the usage identified in paragraph (1), with such market value determined in accordance with Section 16-112 of this Act;

(4) less the following amount which represents the amount to be attributed to new revenue sources and cost reductions by the electric utility through the end of the period for which transition costs are recovered pursuant to Section 16-108, referred to in this Article XVI as a "mitigation factor":

(A) for nonresidential retail customers, an amount equal to the greater of (i) 0.5 cents per kilowatt-hour during the period October 1, 1999 through December 31, 2004, 0.6 cents per kilowatt-hour in calendar year 2005, and 0.9 cents per kilowatt-hour in calendar year 2006, multiplied in each year by the usage identified in paragraph (1), or (ii) an amount equal to the following percentages of the amount produced by applying the applicable base rates (adjusted as described in subparagraph (1)(B)) or contract rate to the usage identified in paragraph (1): 8% for the period October 1, 1999 through December 31, 2002, 10% in calendar years 2003 and 2004, 11% in calendar year 2005 and 12% in calendar year 2006; and

(B) for residential retail customers, an amount equal to the following percentages of the amount produced by applying the base rates in effect on October 1, 1996 (adjusted as described in subparagraph (1)(B)) to the usage identified in paragraph (1): (i) 6% from May 1, 2002 through December 31, 2002, (ii) 7% in calendar years 2003 and 2004, (iii) 8% in calendar year 2005, and (iv) 10% in calendar year 2006;

(5) divided by the usage of such customers identified in paragraph (1),

provided that the transition charge shall never be less than zero.

"Unbundled service" means a component or constituent part of a tariffed service which the electric utility subsequently offers separately to its customers.

(Source: P.A. 97-1128, eff. 8-28-12.)

(220 ILCS 5/16-103)

Sec. 16-103. Service obligations of electric utilities.

(a) An electric utility shall continue offering to retail customers each tariffed service that it offered as a distinct and identifiable service on the effective date of this amendatory Act of 1997 until the service is (i) declared competitive pursuant to Section 16-113, or (ii) abandoned pursuant to Section 8-508. Nothing in this subsection shall be construed as limiting an electric utility's right to propose, or the Commission's power to approve, allow or order modifications in the rates, terms and conditions for such services pursuant to Article IX or Section 16-111 of this Act.

(b) An electric utility shall also offer, as tariffed services, delivery services in accordance with this Article, the power purchase options described in Section 16-110 and real-time pricing as provided in Section 16-107.

(c) Notwithstanding any other provision of this Article, each electric utility shall continue offering to all residential customers and to all small commercial retail customers in its service area, as a tariffed service, bundled electric power and energy delivered to the customer's premises consistent with the bundled utility service provided by the electric utility on the effective date of this amendatory Act of 1997. Upon declaration of the provision of electric power and energy as competitive, the electric utility shall continue to offer to such customers, as a tariffed service, bundled service options at rates which reflect recovery of all cost components for providing the service. For those components of the service which have been declared competitive, cost shall be the market based prices. Market based prices as referred to herein shall mean, for electric power and energy, either (i) those prices for electric power and energy determined as provided in Section 16-112, or (ii) the electric utility's cost of obtaining the electric power and energy at wholesale through a competitive bidding or other arms-length acquisition process.

(d) Any residential or small commercial retail customer which elects delivery services is entitled to return to the electric utility's bundled utility tariffed service offering provided in accordance with subsection (c) of this Section upon payment of a reasonable administrative fee which shall be set forth in the tariff. Notwithstanding any other obligation of an electric utility in this Section: (1) if the residential or small commercial customer has not elected delivery services within 2 billing cycles after returning to the electric utility's bundled utility tariffed service offering, then the electric utility shall be entitled, but not required, to impose the condition that such customer may not elect delivery services for up to 12 months after the date on which the customer returned to bundled utility tariffed service and (2) the electric utility shall be entitled, but not required, to impose the condition that a customer who has left delivery service for the electric utility's bundled service not be permitted to return to the same alternative retail electric supplier within up to 2 billing cycles after the customer returned to bundled utility tariffed service other than in situations, including, but not limited to, where the return was in error, inadvertent, or the result of any other unintended operational consequence.

(e) The Commission shall not require an electric utility to offer any tariffed service other than the services required by this Section, and shall not require an electric utility to offer any competitive service.

(Source: P.A. 99-250, eff. 8-3-15.)

(220 ILCS 5/16-103.1)

Sec. 16-103.1. Tariffed service to Unit Owners' Associations. An electric utility that serves at least 2,000,000 customers must provide tariffed service to Unit Owners' Associations, as defined by Section 2 of the Condominium Property Act, for condominium properties that are not restricted to nonresidential use at rates that do not exceed on average the rates offered to residential customers on an annual basis. Within 10 days after the effective date of this amendatory Act, the electric utility shall provide the tariffed service to Unit Owners' Associations required by this Section and shall reinstate any residential all-electric discount applicable to any Unit Owners' Association that received such a discount on December 31, 2006. For purposes of this Section, "residential customers" means those retail customers of an electric utility that receive (i) electric utility service for household purposes distributed to a dwelling of 2 or fewer units that is billed under a residential rate or (ii) electric utility service for household purposes distributed to a dwelling unit or units that is billed under a residential rate and is registered by a separate meter for each dwelling unit.

(Source: P.A. 95-481, eff. 8-28-07.)

(220 ILCS 5/16-103.2)

Sec. 16-103.2. Market Settlement Service.

(a) Notwithstanding anything to the contrary, an electric utility shall be permitted, at its election, to provide Market Settlement Service, which, for purposes of this Section, shall mean a tariffed, unbundled electric power and energy supply service applicable to all of the electric utility's retail customers having maximum demands exceeding 400 kilowatts, as measured in accordance with the electric utility's retail tariffs, that do not otherwise purchase all of their electric power and energy supply service from the electric utility. Market Settlement Service shall apply to the difference between (i) the actual quantities of electric power and energy supply provided to any such retail customer during a given period and (ii) the quantities of such supply that were deemed to have been provided to such retail customer for the purposes of the applicable regional transmission organization's final wholesale market settlements during that same period. An electric utility providing Market Settlement Service may also, at its election, include in Market Settlement Service electric capacity, transmission services, or other services that are also provided by or through a regional transmission organization to retail customers who receive tariffed electric power and energy supply service with hourly pricing provisions at quantities assigned to such retail customer pursuant to the electric utility's Market Settlement Service tariff. Charges (if the actual quantities provided were greater) or credits (if the actual quantities provided were less) shall be calculated based on the same unit rate or rates set forth in the electric utility's tariff or tariffs for electric power and energy supply service with hourly pricing provisions applicable to its retail customers having maximum demands exceeding 400 kilowatts, provided, however, that any reconciliation provision set forth in such tariff or tariffs, including any charges or credits resulting therefrom, shall not apply to Market Settlement Service.

An electric utility providing Market Settlement Service shall be permitted to recover all of its reasonable and prudently incurred administrative and operational costs of providing this service from all of its retail customers through its delivery services charges. An electric utility providing Market Settlement Service shall be permitted to recover its reasonable and prudent initial implementation and start-up costs from retail consumers having maximum demands exceeding 400 kilowatts through its delivery service charges.

(b) Market Settlement Service shall be provided pursuant to a tariff of the electric utility on file with the Commission. The electric utility's Market Settlement Service tariff shall include provisions for the determination of the quantities subject to Market Settlement Service for any retail customer that receives only a portion of its electric power and energy requirements from an alternative retail electric supplier or electric utility operating outside of its service territory. Notwithstanding subsection (a) of this Section, the electric utility may elect to (i) exclude from Market Settlement Service any portion of the difference described in subsection (a) of this Section attributable to a delayed initial retail electric service bill for a given period and (ii) provide Market Settlement Service limited to an entire retail billing period or periods, without proration, notwithstanding that the applicable regional transmission organization's final wholesale market settlements may have occurred on a date within a retail billing period.

(c) An electric utility that has a tariff in effect pursuant to this Section shall not be subject to, or allowed to pursue, any other claims, adjustments, settlements, or offsets related to the cost of any difference in the actual quantities of electric energy, capacity, transmission services, or other services included in Market Settlement Service, provided, however, that the provisions of this subsection (c) shall not, consistent with the provisions of this Act, (i) preclude any subsequent and separate adjustments made to the same retail customer's electric service account pursuant to a tariff authorized by this Section because of other differences, whether for the same or a different meter or for the same or different period or (ii) reduce or impair in any way an electric utility's authority to charge a retail customer for unmetered electric service related to the retail customer's unlawful tampering with or interference with electric service, including, but not limited to, any other charges allowed by law or the electric utility's tariffs.

(d) A tariff authorized by this Section may be established outside of either (i) a filing seeking a general change in rates under Article IX of this Act or (ii) a filing authorized under Section 16-108.5 of this Act. The Commission shall review and, by order, approve, or approve as modified, the proposed tariff within 180 days after the date on which it is filed. In the event the Commission approves such a tariff with modifications, the electric utility shall not be obligated to place the modified tariff into effect. In such event, the electric utility must, within 14 days after any Commission order, withdraw its proposed tariff and its election to provide Market Settlement Service. If a Market Settlement Service tariff does become effective, such tariff shall remain in effect thereafter at the discretion of the electric utility.

(e) Notwithstanding anything in this Act to the contrary, an electric utility providing Market Settlement Service shall not be liable to any retail customer, alternative retail electric supplier, or electric utility operating outside of its service territory for any adjustment in the quantity of any transmission or retail electric supply service for which the applicable regional transmission organization under its tariffs, agreements, and market and business rules will no longer make a corresponding adjustment to the wholesale market settlements.

(Source: P.A. 98-554, eff. 1-1-14.)

(220 ILCS 5/16-104)

Sec. 16-104. Delivery services transition plan. An electric utility shall provide delivery services to retail customers in accordance with the provisions of this Section.

(a) Each electric utility shall offer delivery services to retail customers located in its service area in accordance with the following provisions:

(1) On or before October 1, 1999, the electric utility shall offer delivery services (i) to any non-residential retail customer whose average monthly maximum electrical demand on the electric utility's system during the 6 months with the customer's highest monthly maximum demands in the 12 months ending June 30, 1999 equals or exceeds 4 megawatts; (ii) to any non-governmental, non-residential, commercial retail customers under common ownership doing business at 10 or more separate locations within the electric utility's service area, if the aggregate coincident average monthly maximum electrical demand of all such locations during the 6 months with the customer's highest monthly maximum electrical demands during the 12 months ending June 30, 1999 equals or exceeds 9.5 megawatts, provided, however, that an electric utility's obligation to offer delivery services under this clause (ii) shall not exceed 3.5% of the maximum electric demand on the electric utility's system in the 12 months ending June 30, 1999; and (iii) to non-residential retail customers whose annual electric energy use comprises 33% of the kilowatt-hour sales, excluding the kilowatt-hour sales to customers described in clauses (i) and (ii), to each non-residential retail customer class of the electric utility.

(2) On or before October 1, 2000, the electric utility shall offer delivery services to the eligible governmental customers described in subsections (a) and (b) of Section 16-125A if the aggregate coincident average monthly maximum electrical demand of such customers during the 6 months with the customers' highest monthly maximum electrical demands during the 12 months ending June 30, 2000 equals or exceeds 9.5 megawatts.

(2.5) On or before June 1, 2000, an electric utility serving more than 1,000,000 customers in this State shall offer delivery services to retail customers whose annual electric energy use comprises 33% of the kilowatt hour sales to that group of retail customers that are classified under Division D, Groups 20 through 39 of the Standard Industrial Classifications set forth in the Standard Industrial Classification Manual published by the United States Office of Management and Budget, excluding the kilowatt-hour sales to those customers that are eligible for delivery services pursuant to clause (1)(i), and shall offer delivery services to its remaining retail customers classified under Division D, Groups 20 through 39 on or before October 1, 2000.

(3) On or before December 31, 2000, the electric utility shall offer delivery services to all remaining nonresidential retail customers in its service area.

(4) On or before May 1, 2002, the electric utility shall offer delivery services to all residential retail customers in its service area.

The loads and kilowatt-hour sales used for purposes of this subsection shall be those for the 12 months ending June 30, 1999 for nonresidential retail customers. The electric utility shall identify those customers to be offered delivery service pursuant to clause (1)(iii) and paragraph (2.5) of subsection (a) of this Section and Section 16-111(e)(B)(iii) pursuant to a lottery or other random nondiscriminatory selection process set forth in the electric utility's delivery services implementation plan pursuant to Section 16-105, which process may include a registration process giving each nonresidential customer the opportunity to register for eligibility for delivery services under this Section, with a lottery of registered customers to be conducted if the annual electric energy use of all registered customers exceeds the limit set forth in clause (1)(iii) or clause (2.5) or Section 16-111(e)(B)(iii), as applicable; provided that the provision of this amendatory Act of 1999 as it relates to the registration and lottery process under clause (1)(iii) is not intended to nor does it make any change in the meaning of this Section, but is intended to remove possible ambiguities, thereby confirming the existing meaning of this Section prior to the effective date of this amendatory Act of 1999. Provided, that non-residential retail customers under common ownership at separate locations within the electric utility's service area may elect, prior to the date the electric utility conducts the lottery or other random selection process for purposes of clause (1)(iii), to designate themselves as a common ownership group, to be excluded from such lottery and to instead participate in a separate lottery for such common ownership group pursuant to which delivery services will be offered to non-residential retail customers comprising 33% of the total kilowatt-hour sales to the common ownership group on or before October 1, 1999. For purposes of this subsection (a), an electric utility may define "common ownership" to exclude sites which are not part of the same business, provided, that auxiliary establishments as defined in the Standard Industrial Classification Manual published by the United States Office of Management and Budget shall not be excluded.

(b) The electric utility shall allow the aggregation of loads that are eligible for delivery services so long as such aggregation meets the criteria for delivery of electric power and energy applicable to the electric utility established by the regional reliability council to which the electric utility belongs, by an independent system operating organization to which the electric utility belongs, or by another organization responsible for overseeing the integrity and reliability of the transmission system, as such criteria are in effect from time to time. The Commission may adopt rules and regulations governing the criteria for aggregation of the loads utilizing delivery services, but its failure to do so shall not preclude any eligible customer from electing delivery services. The electric utility shall allow such aggregation for any voluntary grouping of customers, including without limitation those having a common agent with contractual authority to purchase electric power and energy and delivery services on behalf of all customers in the grouping.

(c) An electric utility shall allow a retail customer that generates power for its own use to include the electrical demand obtained from the customer's cogeneration or self-generation facilities that is coincident with the retail customer's maximum monthly electrical demand on the electric utility's system in any determination of the customer's maximum monthly electrical demand for purposes of determining when such retail customer shall be offered delivery services pursuant to clause (i) of subparagraph (1) of subsection (a) of this Section.

(d) The Commission shall establish charges, terms and conditions for delivery services in accordance with Section 16-108.

(e) Subject to the terms and conditions which the electric utility is entitled to impose in accordance with Section 16-108, a retail customer that is eligible to elect delivery services pursuant to subsection (a) may place all or a portion of its electric power and energy requirements on delivery services.

(f) An electric utility may require a retail customer who elects to (i) use an alternative retail electric supplier or another electric utility for some but not all of its electric power or energy requirements, and (ii) use the electric utility for any portion of its remaining electric power and energy requirements, to place the portion of the customer's electric power or energy requirement that is to be served by the electric utility on a tariff containing charges that are set to recover the lowest reasonably available cost to the electric utility of acquiring electric power and energy on the wholesale electric market to serve such remaining portion of the customer's electric power and energy requirement, reasonable compensation for arranging for and providing such electric power or energy, and the electric utility's other costs of providing service to such remaining electric power and energy requirement.

(Source: P.A. 90-561, eff. 12-16-97; 91-50, eff. 6-30-99.)

(220 ILCS 5/16-105)

Sec. 16-105. Delivery services implementation plan. To ensure the safe and orderly implementation of delivery services, each electric utility shall submit to the Commission no later than March 1, 1999, a delivery services implementation plan for non-residential customers and no later than August 1, 2001, a delivery services implementation plan for residential customers. The delivery services implementation plan shall detail the process and procedures by which each electric utility will offer delivery services to each customer class and shall be designed to insure an orderly transition and the maintenance of reliable service. The Commission shall enter an order approving, or approving as modified, the delivery services implementation plan of each electric utility no later than 60 days prior to the date on which the electric utility must commence offering such services.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-105.5)

Sec. 16-105.5. Rate case filing and revenue-neutral rate design.

(a) An electric utility that files a general rate case pursuant to Section 9-201 of this Act or a Multi-Year Rate Plan pursuant to Section 16-108.18 of this Act may omit the rate design component of such filing and subsequently separately file this component with the Commission, subject to the requirements of subsections (b) and (c) of this Section.

(b) If the electric utility makes the election described in this Section, then the filing shall be consistent with the rate design and cost allocation across customer classes approved in the Commission's most recent order regarding the electric utility's request for a general adjustment to its rates entered under Section 9-201, subsection (e) of Section 16-108.5, or Section 16-108.18 of this Act, as applicable.

(c) If the electric utility makes the election described in this Section, then the following provisions apply to the separate filing of the revenue-neutral rate design component:

(1) No later than one year after the tariffs implementing the general rate case filing or Multi-year Rate Plan filing, as described in subsection (b) of this Section, are placed into effect, the electric utility shall make a filing with the Commission that proposes changes to the tariffs to incorporate the findings of any final rate design orders of the Commission applicable to the electric utility and entered subsequent to the Commission's approval of the tariffs. If no such orders have been entered, then the electric utility must submit its separate revenue-neutral rate design filing no later than 3 years after the date on which the Commission's most recent final rate design order was entered for the electric utility. The electric utility's separate revenue-neutral rate design filing may either propose revenue-neutral tariff changes or refile the existing tariffs without change, which shall present the Commission with an opportunity to suspend the tariffs and consider revenue-neutral tariff changes related to rate design. The Commission shall, after notice and hearing, enter its order approving, or approving with modification, the proposed changes to the tariffs within 240 days after the electric utility's filing. Any changes ordered by the Commission shall become effective at the commencement of the first January monthly billing period that begins no earlier than 30 days after the Commission issues its order adopting such changes.

(2) Following Commission approval under paragraph (1) of this subsection (c), the electric utility shall make a filing with the Commission during each subsequent 3-year period that either proposes revenue-neutral tariff changes or refiles the existing tariffs without change, which shall present the Commission with an opportunity to suspend the tariffs and consider revenue-neutral tariff changes related to rate design. The requirements of this paragraph (2) shall terminate at the time that the electric utility files a general rate case or Multi-Year Rate Plan that includes the rate design component.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-105.6)

Sec. 16-105.6. Amortization of charges or credits.

(a) It is in the public interest to mitigate the customer bill impacts of large expenses incurred by electric utilities by directing that expenses exceeding the applicable threshold specified in this Section be amortized over the prescribed period. Such amortization will levelize customer bill impacts and, in many instances, better align the period of cost recovery with the period over which customers receive the benefit of the expenditure. Accordingly, an electric utility that files a general rate increase under Section 9-201 of this Act or a Multi-Year Rate Plan under Section 16-108.18 of this Act shall amortize, over a 5-year period, each charge or credit that exceeds the applicable amount identified in subsection (b) of this Section and that relates to (1) a workforce reduction program's severance costs; (2) changes in accounting rules; (3) changes in law; (4) compliance with any Commission-initiated audit; and (5) a single storm or weather system, or other similar expense.

Any unamortized balance shall be reflected in rate base.

In this Section, "changes in law" includes any enactment, repeal, or amendment in a law, ordinance, rule, regulation, interpretation, permit, license, consent, or order, including those relating to taxes, accounting, or environmental matters, or in the interpretation or application thereof by any governmental authority occurring after the effective date of this amendatory Act of the 102nd General Assembly.

Nothing in this Section is intended to prohibit the Commission from reviewing the prudence and reasonableness of the costs amortized pursuant to this Section.

(b) An electric utility that serves more than 3,000,000 customers in the State shall amortize the full amount of each charge or credit described in subsection (a) of this Section that exceeds $10,000,000 in the applicable calendar year, and an electric utility that serves less than 3,000,000 customers in the State shall amortize the full amount of each such charge or credit that exceeds $3,700,000 in the applicable calendar year.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-105.7)

Sec. 16-105.7. Revenue balancing adjustments.

(a) It is in the public interest to decouple electric utility sales and revenues, to mitigate the impact on utilities of energy savings goals, to mitigate a utility's disincentive to promote energy efficiency, and to recognize changes in sales attributable to weather, electric vehicles and other electrification, adoption of distributed energy resources, and other volatile or uncontrollable factors without adversely affecting utility customers.

(b) For the purposes of this Section, "reconciliation period" means a period beginning with the January monthly billing period and extending through the December monthly billing period of the same calendar year.

(c) As set forth in subsection (d) of this Section, the Commission shall approve a tariff by which distribution revenues shall be compared annually to the revenue requirement or requirements approved by the Commission on which the rates giving rise to those revenues were based to prevent undercollections or overcollections. An electric utility shall submit an annual revenue balancing reconciliation report to the Commission reflecting the difference between the actual delivery service revenue and multi-year rate case revenue requirement for the applicable reconciliation and identifying the charges or credits to be applied thereafter. Such reconciliation and calculation of associated charges or credits shall be conducted on a customer class basis. The annual revenue balancing reconciliation report shall be filed with the Commission no later than March 20 of the year following a reconciliation period. The Commission may initiate a review of the revenue balancing reconciliation report each year to determine if any subsequent adjustment is necessary to align actual delivery service revenue and rate case revenue requirement. If the Commission elects to initiate such review, the Commission shall, after notice and hearing, enter an order approving, or approving as modified, such revenue balancing reconciliation report no later than 120 days after the utility files its report with the Commission. If the Commission does not initiate such a review, the revenue balancing reconciliation report and the identified charges or credits shall be deemed accepted and approved 120 days after the utility files the report and shall not be subject to review in any other proceeding. Any balancing adjustment shall take effect during the following January monthly billing period.

(d) Each electric utility shall file a tariff in compliance with the provisions of this Section within 120 days after the effective date of this amendatory Act of the 102nd General Assembly. The Commission shall approve the tariff if it finds that it is consistent with the provisions of the Section. If the Commission does not so find, it shall approve the tariff with modification to conform it to the requirements of this Section or otherwise reject the tariff and explain how the utility can modify the tariff and refile to comply with the requirements of this Section.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-105.10)

Sec. 16-105.10. Independent baseline assessment.

(a) Prior to the filing of the initial Multi-Year Integrated Grid Plan described in Section 16-105.17 of this Act, the General Assembly finds that an independent audit of the current state of the grid, and of the expenditures made since 2012, will need to be made.

Specifically, the General Assembly finds:

(1) Pursuant to the Energy Infrastructure Modernization Act and subsequent clarifying legislation, electric utilities in this State that serve over 300,000 retail customers have made substantial investments in the grid and advanced metering infrastructure.

(2) Before a Multi-Year Integrated Grid Plan is filed under Section 16-105.17, it is necessary to understand the benefits of these investments to the grid and to customers and to evaluate the current condition of the distribution grid.

(3) It is also necessary for electric utilities, the Commission, and stakeholders to have an independently verified set of data to establish the baseline for future distribution grid spending.

(4) The Commission has authority to order and implement the requirements of this Section under Section 8-102 of this Act.

(b) Terms used in this Section have the meanings given to those terms in Sections 16-102, 16-107.6, and 16-108 of this Act.

(c) Within 30 days after the effective date of this amendatory Act of the 102nd General Assembly, the Commission shall issue an order initiating an audit of each electric utility serving over 300,000 retail customers in the State, which shall examine the following:

(1) An assessment of the distribution grid, as described in paragraph (2) of subsection (a) of this Section. The Commission shall have the authority to require additional items which it deems necessary.

(2) An analysis of the utility's capital projects placed into service in the preceding 9 years, including, but not limited to, assessing the value of deploying advanced metering infrastructure to modernize and optimize the grid and deliver value to customers.

(3) An analysis of the utility's initiatives to optimize the reliability and resiliency of the grid, other than through capital spending.

(4) Creation of a data baseline to inform the beginning of the multi-year integrated grid planning process described in Section 16-105.17 of this Act.

(5) Identification of any deficiencies in data which may impact the planning process.

(d) It is contemplated that the auditor will utilize materials filed with the Commission by the utilities with respect to their expenditures in the preceding 9 years; however, the auditor may also, with Commission approval, assess other information deemed necessary to make its report.

(e) The results of the audit described in this Section shall be reflected in a report delivered to the Commission, describing the information specified in this Section. Such report is to be delivered no later than 180 days after the Commission enters its order pursuant to subsection (c) of this Section. It is understood that any public report may not contain items that are confidential or proprietary.

(f) The costs of an electric utility's audit described in this Section shall not exceed $500,000 and shall be paid for by the electric utility that is the subject of the audit. Such costs shall be a recoverable expense.

(g) The Commission shall have the authority to retain the services of an auditor to assist with the distribution planning process, as well as in docketed proceedings. Such expenses for these activities shall also be borne by the Commission.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-105.17)

Sec. 16-105.17. Multi-Year Integrated Grid Plan.

(a) The General Assembly finds that ensuring alignment of regulated utility operations, expenditures, and investments with public benefit goals, including safety, reliability, resiliency, affordability, equity, emissions reductions, and expansion of clean distributed energy resources, is critical to maximizing the benefits of the interconnected utility grid and cost-effective utility expenditures on the grid. It is the policy of the State to promote inclusive, comprehensive, transparent, cost-effective distribution system planning and disclosures processes that minimize long-term costs for Illinois customers and support the achievement of State renewable energy development and other clean energy, public health, and environmental policy goals. Utility distribution system expenditures, programs, investments, and policies must be evaluated in coordination with these goals. In particular, the General Assembly finds that:

(1) Investment in infrastructure to support and enable existing and new distributed energy resources creates significant economic development, environmental, and public health benefits in the State.

(2) Illinois' electricity distribution system must cost-effectively integrate renewable energy resources, including utility-scale renewable energy resources, community renewable generation, and distributed renewable energy resources, support beneficial electrification, including electric vehicle use and adoption, promote opportunities for third-party investment in nontraditional, grid-related technologies and resources such as batteries, solar photovoltaic panels, and smart thermostats, reduce energy usage generally and especially during times of greatest reliance on fossil fuels, and enhance customer engagement opportunities.

(3) Inclusive distribution system planning is an essential tool for the Commission, public utilities, and stakeholders to effectively coordinate environmental, consumer, reliability, and equity goals at fair and reasonable costs, and for ensuring transparent utility accountability for meeting those goals.

(4) Any planning process should advance Illinois energy policy goals while ensuring utility investments are cost-effective. Such a process should maximize the sharing of information, minimize overlap with existing filing requirements to ensure robust stakeholder participation, and recognize the responsibility of the utility to manage the grid in a safe, reliable manner.

(5) The General Assembly is concerned that, in the absence of a transparent, meaningful distribution system planning process, utility investments may not always serve customers' best interests, appropriately promote the expansion of clean distributed energy resources, and advance equity and environmental justice.

(6) The General Assembly is also encouraged by the opportunities presented by nontraditional solutions to utility, customer, and grid needs that may be more efficient and cost-effective, and less environmentally harmful than traditional solutions. Nontraditional solutions include distributed energy resources owned or implemented by customers and independent third parties, controllable load, beneficial electrification, or rate design that encourages efficient energy use.

(7) The General Assembly finds that Illinois utilities' current processes for planning their distribution system should be made more accessible and transparent to individuals and communities, and that more inclusive and accessible distribution system planning processes would be in the interests of all Illinois residents.

(8) The General Assembly finds it would be beneficial to require utilities to demonstrate how their spending promotes identified State clean energy goals, such as integrating renewable energy, empowering customers to make informed choices, supporting electric vehicles, beneficial electrification, and energy storage, achieving equity goals, enhancing resilience, and maintaining reliability.

The General Assembly therefore directs the utilities to implement distribution system planning as described in this Section in order to accelerate progress on Illinois clean energy and environmental goals and hold electric utilities publicly accountable for their performance.

(b) Unless otherwise specified, the terms used in this Section shall have the same meanings as defined in Sections 16-102 and 16-107.6. As used in this Section:

"Demand response" means measures that decrease peak electricity demand or shift demand from peak to off-peak periods.

"Distributed energy resources" or "DER" means a wide range of technologies that are connected to the grid, including those that are located on the customer side of the customer's electric meter and can provide value to the distribution system, including, but not limited to, distributed generation, energy storage, electric vehicles, and demand response technologies.

"Environmental justice communities" means the definition of that term based on existing methodologies and findings, used and as may be updated by the Illinois Power Agency and its Program Administrator in the Illinois Solar for All Program.

(c) This Section applies to electric utilities serving more than 500,000 retail customers in the State.

(d) The Multi-Year Integrated Grid Plan ("the Plan") shall be designed to:

(1) ensure coordination of the State's renewable energy goals, climate and environmental goals with the utility's distribution system investments, and programs and policies over a 5-year planning horizon to maximize the benefits of each while ensuring utility expenditures are cost-effective;

(2) optimize utilization of electricity grid assets and resources to minimize total system costs;

(3) support efforts to bring the benefits of grid modernization and clean energy, including, but not limited to, deployment of distributed energy resources, to all retail customers, and support efforts to bring at least 40% of the benefits of those benefits to Equity Investment Eligible Communities. Nothing in this paragraph is meant to require a specific amount of spending in a particular geographic area;

(4) enable greater customer engagement, empowerment, and options for energy services;

(5) reduce grid congestion, minimize the time and expense associated with interconnection, and increase the capacity of the distribution grid to host increasing levels of distributed energy resources, to facilitate availability and development of distributed energy resources, particularly in locations that enhance consumer and environmental benefits;

(6) ensure opportunities for robust public participation through open, transparent planning processes.

(7) provide for the analysis of the cost-effectiveness of proposed system investments, which takes into account environmental costs and benefits;

(8) to the maximum extent practicable, achieve or support the achievement of Illinois environmental goals, including those described in Section 9.10 of the Environmental Protection Act and Section 1-75 of the Illinois Power Agency Act, and emissions reductions required to improve the health, safety, and prosperity of all Illinois residents;

(9) support existing Illinois policy goals promoting the long-term growth of energy efficiency, demand response, and investments in renewable energy resources;

(10) provide sufficient public information to the Commission, stakeholders, and market participants in order to enable nonemitting customer-owned or third-party distributed energy resources, acting individually or in aggregate, to seamlessly and easily connect to the grid, provide grid benefits, support grid services, and achieve environmental outcomes, without necessarily requiring utility ownership or controlling interest over those resources, and enable those resources to act as alternatives to utility capital investments; and

(11) provide delivery services at rates that are affordable to all customers, including low-income customers.

(e) Plan Development Stakeholder Process.

(1) To promote the transparency of utility distributions system planned investments and the planning process for those investments, the Commission shall convene a workshop process, over a period of no less than 5 months, for each such utility for the purpose of establishing an open, inclusive, and cooperative forum regarding such investments. The workshops shall be facilitated by an independent, third-party facilitator selected by the Commission. Data and projections provided through the workshop process shall be designed to provide participants with information about the electric utility's (i) historic distribution system investments for at least the 5 years prior to the year in which the workshop is held and (ii) planned investments for the 5-year period following the year in which the workshop is held. The workshop process shall recognize that estimates for later years will be less reliable and indicative of future conduct than estimates for earlier years and that the electric utility is subject to financial and system planning processes. No later than January 1, 2022, the facilitator shall initiate a series of workshops for each electric utility subject to this Section. The series of workshops shall include no fewer than 6 workshops and shall conclude no later than June 1, 2022.

(2) The workshops shall be designed to achieve the following objectives:

(A) review utilities' planned capital investments and supporting data;

(B) review how utilities plan to invest in their distribution system in order to meet the system's projected needs;

(C) review system and locational data on reliability, resiliency, DER, and service quality provided by the utilities;

(D) solicit and consider input from diverse stakeholders, including representatives from environmental justice communities, geographically diverse communities, low-income representatives, consumer representatives, environmental representatives, organized labor representatives, third-party technology providers, and utilities;

(E) consider proposals from utilities and stakeholders on programs and policies necessary to achieve the objectives in subsection (d) of this Section;

(F) consider proposals applicable to each component of the utilities' Multi-Year Integrated Grid Plan filings under paragraph (2) of subsection (f) of this Section;

(G) educate and equip interested stakeholders so that they can effectively and efficiently provide feedback and input to the electric utility; and

(H) review planned capital investment to ensure that delivery services are provided at rates that are affordable to all customers, including low-income customers.

(3) To the extent any of the information in subparagraphs (A) through (H) of paragraph (2) of this subsection is designated as confidential and proprietary under the Commission's rules, the proponent of the designation shall have the burden of making the requisite showing under the Commission's rules. For data that is determined to be confidential or that includes personally identifiable information, the Commission may develop procedures and processes to enable data sharing with parties and stakeholders while ensuring the confidentiality of the information.

(4) Workshops should be organized and facilitated in a manner that encourages representation from diverse stakeholders, ensuring equitable opportunities for participation, without requiring formal intervention or representation by an attorney. Workshops should be held during both day and evening hours, in a variety of locations within each electric utility's service territory, and should allow remote participation.

(5) It is a goal of the State that this workshop process will provide a forum for interested stakeholders to effectively and efficiently provide feedback and input to the electric utility. It is also a goal of the State that stakeholder participation in this process will prepare stakeholders to more capably participate in Multi-Year Rate Plan proceedings conducted pursuant to Section 16-108.18 of this Act, if they so elect. As part of the workshop process, the electric utility shall submit to the Commission the electric utility's capital investments proposal, and supporting data described in subparagraphs (A) through (C) of paragraph (2) of this subsection (e) before the start of workshops to allow interested stakeholders to reasonably review data before attending workshops. The Commission shall make public the utility capital investments proposal by posting it on the Commission's website and set the location and time of any workshop to be held as part of the workshop process, and establish a data request process, consistent with the Commission's rules, that affords workshop participants opportunities to submit data requests to the utility, and receive responses in accordance with the utility's obligations under the law, prior to the workshop, regarding the information described in this paragraph (5). Upon the written request of a workshop participant, the utility shall also present at a given workshop at least one appropriate company representative who can address the specific written questions or written categories of questions identified in advance by the workshop participant regarding issues related to the utility's Multi-Year Integrated Grid Plan. To facilitate public feedback, the administrator facilitating the workshops shall, throughout the workshop process, develop questions for stakeholder input on topics being considered. This may include, but is not limited to: design of the workshop process, locational data and information provided by utilities, alignment of plans, programs, investments and objectives, and other topics as deemed appropriate by the Commission facilitation staff. Stakeholder feedback shall not be limited to these questions. The information provided as part of the workshop process pursuant to this subsection (e) is intended to be informational and to provide a preliminary view of costs and investments, which may change. Accordingly, the information provided pursuant to this subsection (e) shall not be binding on the utility and shall not be the sole basis for a finding in any Commission proceeding of imprudence, unreasonableness, or lack of use or usefulness of any individual or aggregate level of utility plant or other investment or expenditure addressed; however, information contained in the plan may be used in a proceeding before the Commission, with weight of such evidence to be determined by the Commission.

(6) Workshops shall not be considered settlement negotiations, compromise negotiations, or offers to compromise for the purposes of Illinois Rule of Evidence 408. All materials shared as a part of the workshop process, and that are not determined to be confidential as described in paragraph (3) of this subsection (e), shall be made publicly available on a website made available by the Commission.

(7) On conclusion of the workshops, the Commission shall open a comment period that allows interested and diverse stakeholders to submit comments and recommendations regarding the utility's Multi-Year Integrated Grid Plan filing. Based on the workshop process and stakeholder comments and recommendations offered verbally or in writing during the workshops and in writing during the comment period following the workshops, the independent third-party facilitator shall prepare a report, to be submitted to the Commission no later than July 1, 2022, describing the stakeholders, discussions, proposals, and areas of consensus and disagreement from the workshop process, and making recommendations to the Commission regarding the utility's Multi-Year Integrated Grid Plan. Interested stakeholders shall have an opportunity to provide comment on the independent third-party facilitator report.

(8) Based on discussions in the workshops, the independent third-party facilitator report, and stakeholder comments and recommendations made during and following the workshop process, the Commission shall issue initiating orders no later than August 1, 2022, requiring the electric utilities subject to this Section to file the first Multi-Year Integrated Grid Plan no later than January 20, 2023. The initiating orders shall specify the requirements applicable to the utilities' Multi-Year Integrated Grid Plans, which shall supplement and not replace those requirements described in subsection (f) of this Section.

(f) Multi-Year Integrated Grid Plan.

(1) Pursuant to this subsection (f) and the initiating orders of the Commission, each electric utility subject to this Section shall, no later than January 20, 2023, submit its first Multi-Year Integrated Grid Plan. No later than January 20, 2026, and every 4 years thereafter, the utility shall submit its subsequent Plan. Each Plan shall:

(A) incorporate requirements established by the Commission in its initiating order; and

(B) propose distribution system investment programs, policies, and plans designed to optimize achievement of the objectives set forth in subsection (d) of this Section and achieve the metrics approved by the Commission pursuant to Section 16-108.18 of this Act.

To the extent practicable and reasonable, all programs, policies, and initiatives proposed by the utility in its plan should be informed by stakeholder input received during the workshop process pursuant to subsection (e) of this Section. Where specific stakeholder input has not been incorporated in proposed programs, policies, and plans, the electric utility shall provide an explanation as to why that input was not incorporated.

(2) In order to ensure electric utilities' ability to meet the goals and objectives set forth in this Section, the Multi-Year Integrated Grid Plans must include, at minimum, the following information:

(A) A description of the utility's distribution system planning process, including:

(i) the overview of the process, including frequency and duration of the process, roles, and responsibilities of utility personnel and departments involved;

(ii) a summary of the meetings with stakeholders conducted prior to filing of the plan with the Commission.

(iii) the description of any coordination of the processes with any other planning process internal or external to the utility, including those required by a regional transmission operator.

(B) A detailed description of the current operating conditions for the distribution system separately presented for each of the utility's operating areas, where possible, including a detailed description, with supporting data, of system conditions, including baseline data regarding the utility's distribution system from the utility's annual report to the Commission, total distribution system substation capacity in kVa, total miles of primary overhead distribution wire, and total miles of primary underground distribution cable, distributed energy resource deployment by type, size, customer class, and geographic dispersion as to those DERs that have completed the interconnection process, the most current distribution line loss study, current and expected System Average Interruption Frequency Index and Customer Average Interruption Duration Index data for the system, identification of the system model software currently used and planned software deployments, and other data needs as requested by the Commission or as determined through Commission rules. The description shall also include the utility's most recent system load and peak demand forecast for at least the next 5 years, and up to 10 years if available, a discussion of how the forecast was prepared and how distributed energy resources and energy efficiency were factored into the forecast, and identification of the forecasting software currently used and planned software deployments.

(C) Financial Data.

(i) For each of the preceding 5 years, the utility's distribution system investments by the investment categories tracked by the utility, including, but not limited to, new business, facility relocation, capacity expansion, system performance, preventive maintenance, corrective maintenance, the total amount of investments associated with the integration of DERs, the total amount of charges to DER developers and retail customers for interconnection of DERs to the distribution system, and a list of each major investment category the utility used to maintain its routine standing operational activities and the associated plant in service amount for each category in which the plant in service amount is at least $2,000,000;

(ii) For each of the preceding 5 years, data on and a discussion of the utility's distribution system operation and maintenance expenses;

(iii) A 5-year long-range forecast of distribution system capital investments and operational and maintenance expenses, including a discussion of any projections for expenses for the categories listed in subparagraph (i) of this item (C).

(D) System data on DERs on the utility's distribution system, including the total number and nameplate capacity of DERs that completed interconnection in the prior year, current DER deployment by type, size, and geographic dispersion, to the extent that granular geographic information does not disclose personally identifiable information, and other data as requested by the Commission or determined by Commission rules.

(E) Hosting Capacity and Interconnection Requirements.

(i) The utility shall make available on its website the hosting capacity analysis results that shall include mapping and GIS capability, as well as any other requirements requested by the Commission or determined through Commission rules. The plan shall identify where the hosting capacity analysis results shall be made publicly available. This shall also include an assessment of the impact of utility investments over the next 5 years on hosting capacity and a narrative discussion of how the hosting capacity analysis advances customer-sited distributed energy resources, including electric vehicles, energy storage systems, and photovoltaic resources, and how the identification of interconnection points on the distribution system will support the continued development of distributed energy resources.

(ii) Discussion of the utility's interconnection requirements and how they comply with the Commission's applicable regulations.

(F) Identification and discussion of the scenarios considered in the development of the utility's Multi-Year Integrated Grid Plan, including DER scenarios, and discussion of base-case and alternative scenarios, how the scenarios were developed and selected, and how the scenarios include a reasonable mix of DERs scenarios, types, and geographic dispersion. Scenarios shall at least consider the 5-year forecast horizon of the Multi-Year Integrated Grid Plan, but may also consider longer-term scenarios where data is available. The plan shall also include requirements requested by the Commission or determined through Commission rules.

(G) An evaluation of the short-term and long-run benefits and costs of distributed energy resources located on the distribution system, including, but not limited to, the locational, temporal, and performance-based benefits and costs of distributed energy resources. The utility shall use the results of this evaluation to inform its analysis of Solution Sourcing Opportunities, including nonwires alternatives, under subparagraph (K) of paragraph (2) subsection (f) of this Section. The Commission may use the data produced through this evaluation to, among other use-cases, inform the Commission's investigation and establishment of tariffs and compensation for distributed energy resources interconnecting to the utility's distribution system, including rebates provided by the electric utility pursuant to Section 16-107.6 of this Act.

(H) Long-term Distribution System Investment Plan.

(i) The utility's planned distribution capital investments for the period covered by the planning process required by this Section, by the investment categories used by the utility, and with discussion of any individual planned projects with a planned total investment gross amount of $3,000,000 or more and of the alternatives considered by the utility to such individual projects including any non-traditional alternatives and DER alternatives, and supporting data. This shall provide sufficiently detailed explanations of how the planned investments shall support the goals in subsection (d) of this Section.

(ii) Discussion of how the utility's capital investments plan is consistent with Commission orders regarding the procurement of renewable resources as discussed in Section 16-111.5 of this Act, energy efficiency plans as discussed in Section 8-103B, distributed generation rebates as discussed in Section 16-107.6, and any other Commission order affecting the goals described in subsection (d) of this Section.

(iii) A plan for achieving the applicable metrics that were approved by the Commission for the utility pursuant to subsection (e) of Section 16-108.18 of this Act.

(iv) A narrative discussion of the utility's vision for the distribution system over the next 5 years.

(v) Any additional information requested by the Commission or determined through Commission rules.

(I) A detailed description of historic distribution system operations and maintenance expenditures for the preceding 5 years and of planned or projected operations and maintenance expenditures for the period covered by the planning process required by this Section, as well as the data, reasoning and explanation supporting planned or projected expenditures. Any additional information requested by the Commission or determined through Commission rules.

(J) A detailed plan for achieving the applicable metrics that were approved by the Commission for the utility pursuant to subsection (e) of Section 16-108.18 of this Act, including, but not limited to, the following:

(i) A description of, exclusive of low-income rate relief programs and other income-qualified programs, how the utility is supporting efforts to bring 40% of benefits from programs, policies, and initiatives proposed in their Multi-Year Integrated Grid Plan to ratepayers in low-income and environmental justice communities. This shall also include any information requested by the Commission or determined through Commission rules. Nothing in this subparagraph is meant to require a specific amount of spending in a particular geographic area.

(ii) A detailed analysis of current and projected flexible resources, including resource type, size (in MW and MWh), location and environmental impact, as well as anticipated needs that can be met using flexible resources, to meet the goals described in subsection (d) of this Section, to meet the applicable metrics that were approved by the Commission for the utility pursuant to subsection (e) of Section 16-108.18 of this Act, and any other Commission order affecting the goals described in subsection (d) of this Section.

(iii) Any additional information requested by the Commission or determined through Commission rules.

(K) Identification of potential cost-effective solutions from nontraditional and third-party owned investments that could meet anticipated grid needs, including, but not limited to, distributed energy resources procurements, tariffs or contracts, programmatic solutions, rate design options, technologies or programs that facilitate load flexibility, nonwires alternatives, and other solutions that are intended to meet the objectives described at subsection (d). It is the policy of this State that cost-effective third-party or customer-owned distributed energy resources create robust competition and customer choice and shall be considered as appropriate. The Commission shall establish rules determining data or methods for Solution Sourcing Opportunities.

(L) A detailed description of the utility's interoperability plan, which must describe the manner in which the electric utility's current and planned distribution system investments will work together and exchange information and data, the extent to which the utility is implementing open standards and interfaces with third-party distributed energy resource owners and aggregators, and the utility's plan for interoperability testing and certification.

(3) To the extent any information in utilities' Multi-Year Integrated Grid Plans is designated as confidential and proprietary under the Commission's rules, the proponent of the designation shall have the burden of making the requisite showing under the Commission's rules. For data that is determined to be confidential or that includes personally identifiable information, the Commission may develop procedures and processes to enable data sharing with parties and stakeholders while ensuring the confidentiality of the information. All confidential information exchanged, submitted, or shared by a utility pursuant to this Section shall be protected from intentional and accidental dissemination. The Commission shall have authority to supervise, protect, and restrict access to all confidential, commercially sensitive, or system security related information and data, and shall be authorized to take all necessary steps to protect that information from unauthorized disclosure. This paragraph shall not be interpreted to require a utility to make publicly available any information or data that could compromise the physical or cyber security of a utility's distribution system. Any party that accidentally disseminates confidential information obtained pursuant to a proceeding initiated in accordance with this Section, or is the victim of a cyber-security breach, must notify the affected utility, the Illinois Attorney General, and the Commission staff with 24 hours of knowledge of such dissemination or breach. Any party that fails to provide required notification of such a breach shall be subject to remedies available to the Commission and the Illinois Attorney General.

(4) It is the policy of this State that holistic consideration of all related investments, planning processes, tariffs, rate design options, programs, and other utility policies and plans shall be required. To that end, the Commission shall consider, comprehensively, the impact of all related plans, tariffs, programs, and policies on the Plan and on each other, including:

(A) time-of-use pricing program pursuant to Section 16-107.7 of this Act, hourly pricing program pursuant to Section 16-107 of this Act, and any other time-variant or dynamic pricing program;

(B) distributed generation rebate pursuant to Section 16-107.6 of this Act;

(C) net electricity metering, pursuant to Section 16-107.5 of this Act;

(D) energy efficiency programs pursuant to Section 8-103B of this Act;

(E) beneficial electrification programs pursuant to Section 16-107.8 of this Act;

(F) Equitable Energy Upgrade Program pursuant to Section 16-111.10 of this Act;

(G) renewable energy programs and procurements set forth in the Illinois Power Agency Act, including, but not limited to, those set forth in the long-term renewable resources procurement plan developed pursuant to Section 1-20 of that Act; and

(H) other plans, programs, and policies that are relevant to distribution grid investments, costs, planning, and other categories as requested by the Commission.

The Plan shall comprehensively detail the relationship between these plans, tariffs, and programs and to the electric utility's achievement of the objectives in subsection (d). The Plan shall be designed to coordinate each of these plans, programs, and tariffs with the electric utility's long-term distribution system investment planning in order to maximize the benefits of each.

(5) The initiating order for the initial Multi-Year Integrated Grid Plan, as well as each electric utility's subsequent Integrated Grid Plans under subsection (g), shall begin a contested proceeding as described in subsection (d) of Section 10-101.1 of this Act.

(A) In evaluating a utility's Plan, the Commission shall consider, at minimum, whether the Plan:

(1) meets the objectives of this Section;

(2) includes the components in paragraph (2) of subsection (f) of this Section;

(3) considers and incorporates, where practicable, input from interested stakeholders, including parties and people who offer public comment without legal representation;

(4) considers nontraditional, including third-party owned, investment alternatives that can meet grid needs and provide additional benefits (including consumer, economic, and environmental benefits) beyond comparable, traditional utility-planned capital investments;

(5) equitably benefits environmental justice communities; and

(6) maximizes consumer, environmental, economic, and community benefits over a 10-year horizon.

(B) The Commission, after notice and hearing, shall modify each electric utility's Plan as necessary to comply with the objectives of this Section. The Commission may approve, or modify and approve, a Plan only if it finds that the Plan is reasonable, complies with the objectives and requirements of this Section, and reasonably incorporates input from parties. The Commission may reject each electric utility's Plan if it finds that the Plan does not comply with the objectives and requirements of this Section. If the Commission enters an order rejecting a Plan, the utility must refile a Plan within 3 months after that order, and until the Commission approves a Plan, the utility's existing Plan will remain in effect.

(C) For the initial Integrated Grid Plan filings, the Commission shall enter an order approving, modifying, or rejecting the Plan no later than December 15, 2023. For subsequent Integrated Grid Plan filings, the Commission shall enter an order approving, modifying, or rejecting the Plan no later than December 15 of the year in which it was filed.

(D) Each electric utility shall file its proposed Initial Multi-Year Integrated Grid Plan no later than January 20, 2023. Prior to that date and following the initiating order, the Commission shall initiate a case management conference and shall take any appropriate steps to begin meaningful consideration of issues, including enabling interested parties to begin conducting discovery.

(6) As part of its order approving a utility's Multi-Year Integrated Grid Plan, including any modifications required, the Commission may create a subsequent implementation plan docket, or multiple implementation plan dockets, if the Commission determines that multiple dockets would be preferable, to consider a utility's detailed plan or plans, as directed in the Commission's order.

(g) No later than January 20, 2026 and every 4 years thereafter, each electric utility subject to this Section shall file a new Multi-Year Integrated Grid Plan for the subsequent 4 delivery years after the completion of the then-effective Plan. Each Plan shall meet the requirements described in subsection (f) of this Section, and shall be preceded by a workshop process which meets the same requirements described in subsection (e). If appropriate, the Commission may require additional implementation dockets to follow Subsequent Multi-Year Integrated Grid Plan filings.

(h) During the period leading to approval of the first Multi-Year Integrated Grid Plan, each electric utility will necessarily continue to invest in its distribution grid. Those investments will be subject to a determination of prudence and reasonableness consistent with Commission practice and law. Any failure of such investments to conform to the Multi-Year Integrated Grid Plan ultimately approved shall not imply imprudence or unreasonableness.

(i) The Commission shall adopt rules to carry out the provisions of this Section under the emergency rulemaking provisions set forth in Section 5-45 of the Illinois Administrative Procedure Act, and such emergency rules may be effective no later than 90 days after the effective date of this amendatory Act of the 102nd General Assembly.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-106)

Sec. 16-106. Billing experiments. During the mandatory transition period, an electric utility may at its discretion conduct one or more experiments for the provision or billing of services on a consolidated or aggregated basis, for the provision of real-time pricing, or other billing or pricing experiments, and may include experimental programs offered to groups of retail customers possessing common attributes as defined by the electric utility, such as the members of an organization that was established to serve a well-defined industry group, companies having multiple sites, or closely located or affiliated buildings, provided that such groups exist for a purpose other than obtaining energy services and have been in existence for at least 10 years. The offering of such a program by an electric utility to retail customers participating in the program, and the participation by those customers in the program, shall not create any right in any other retail customer or group of customers to participate in the same or a similar program. The Commission shall allow such experiments to go into effect upon the filing by the electric utility of a statement describing the program. Nothing contained in this Section shall be deemed to prohibit the electric utility from offering, or the Commission from approving, experimental rates, tariffs and services in addition to those allowed under this Section. The Commission shall review and report annually the progress, participation and effects of such experiments to the General Assembly. Based upon its review, recommendations for modification of such experiments may be made by the Commission to the Illinois General Assembly.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-107)

Sec. 16-107. Real-time pricing.

(a) Each electric utility shall file, on or before May 1, 1998, a tariff or tariffs which allow nonresidential retail customers in the electric utility's service area to elect real-time pricing beginning October 1, 1998.

(b) Each electric utility shall file, on or before May 1, 2000, a tariff or tariffs which allow residential retail customers in the electric utility's service area to elect real-time pricing beginning October 1, 2000.

(b-5) Each electric utility shall file a tariff or tariffs allowing residential retail customers in the electric utility's service area to elect real-time pricing beginning January 2, 2007. The Commission may, after notice and hearing, approve the tariff or tariffs. A tariff or tariffs approved pursuant to this subsection (b-5) shall, at a minimum, describe (i) the methodology for determining the market price of energy to be reflected in the real-time rate and (ii) the manner in which customers who elect real-time pricing will be provided with ready access to hourly market prices, including, but not limited to, day-ahead hourly energy prices. A customer who elects real-time pricing under a tariff approved under this subsection (b-5) and thereafter terminates the election shall not return to taking service under the tariff for a period of 12 months following the date on which the customer terminated real-time pricing. However, this limitation shall cease to apply on such date that the provision of electric power and energy is declared competitive under Section 16-113 of this Act for the customer group or groups to which this subsection (b-5) applies.

A proceeding under this subsection (b-5) may not exceed 120 days in length.

(b-10) Each electric utility providing real-time pricing pursuant to subsection (b-5) shall install a meter capable of recording hourly interval energy use at the service location of each customer that elects real-time pricing pursuant to this subsection.

(b-15) If the Commission issues an order pursuant to subsection (b-5), the affected electric utility shall contract with an entity not affiliated with the electric utility to serve as a program administrator to develop and implement a program to provide consumer outreach, enrollment, and education concerning real-time pricing and to establish and administer an information system and technical and other customer assistance that is necessary to enable customers to manage electricity use. The program administrator: (i) shall be selected and compensated by the electric utility, subject to Commission approval; (ii) shall have demonstrated technical and managerial competence in the development and administration of demand management programs; and (iii) may develop and implement risk management, energy efficiency, and other services related to energy use management for which the program administrator shall be compensated by participants in the program receiving such services. The electric utility shall provide the program administrator with all information and assistance necessary to perform the program administrator's duties, including, but not limited to, customer, account, and energy use data. The electric utility shall permit the program administrator to include inserts in residential customer bills 2 times per year to assist with customer outreach and enrollment.

The program administrator shall submit an annual report to the electric utility no later than April 1 of each year describing the operation and results of the program, including information concerning the number and types of customers using real-time pricing, changes in customers' energy use patterns, an assessment of the value of the program to both participants and non-participants, and recommendations concerning modification of the program and the tariff or tariffs filed under subsection (b-5). This report shall be filed by the electric utility with the Commission within 30 days of receipt and shall be available to the public on the Commission's web site.

(b-20) The Commission shall monitor the performance of programs established pursuant to subsection (b-15) and shall order the termination or modification of a program if it determines that the program is not, after a reasonable period of time for development not to exceed 4 years, resulting in net benefits to the residential customers of the electric utility.

(b-25) An electric utility shall be entitled to recover reasonable costs incurred in complying with this Section, provided that recovery of the costs is fairly apportioned among its residential customers as provided in this subsection (b-25). The electric utility may apportion costs on the residential customers who elect real-time pricing, but may also impose some of the costs of real-time pricing on customers who do not elect real-time pricing.

(c) The electric utility's tariff or tariffs filed pursuant to this Section shall be subject to Article IX.

(d) This Section does not apply to any electric utility providing service to 100,000 or fewer customers.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-107.5)

Sec. 16-107.5. Net electricity metering.

(a) The General Assembly finds and declares that a program to provide net electricity metering, as defined in this Section, for eligible customers can encourage private investment in renewable energy resources, stimulate economic growth, enhance the continued diversification of Illinois' energy resource mix, and protect the Illinois environment. Further, to achieve the goals of this Act that robust options for customer-site distributed generation continue to thrive in Illinois, the General Assembly finds that a predictable transition must be ensured for customers between full net metering at the retail electricity rate to the distribution generation rebate described in Section 16-107.6.

(b) As used in this Section, (i) "community renewable generation project" shall have the meaning set forth in Section 1-10 of the Illinois Power Agency Act; (ii) "eligible customer" means a retail customer that owns, hosts, or operates, including any third-party owned systems, a solar, wind, or other eligible renewable electrical generating facility that is located on the customer's premises or customer's side of the billing meter and is intended primarily to offset the customer's own current or future electrical requirements; (iii) "electricity provider" means an electric utility or alternative retail electric supplier; (iv) "eligible renewable electrical generating facility" means a generator, which may include the co-location of an energy storage system, that is interconnected under rules adopted by the Commission and is powered by solar electric energy, wind, dedicated crops grown for electricity generation, agricultural residues, untreated and unadulterated wood waste, livestock manure, anaerobic digestion of livestock or food processing waste, fuel cells or microturbines powered by renewable fuels, or hydroelectric energy; (v) "net electricity metering" (or "net metering") means the measurement, during the billing period applicable to an eligible customer, of the net amount of electricity supplied by an electricity provider to the customer or provided to the electricity provider by the customer or subscriber; (vi) "subscriber" shall have the meaning as set forth in Section 1-10 of the Illinois Power Agency Act; (vii) "subscription" shall have the meaning set forth in Section 1-10 of the Illinois Power Agency Act; (viii) "energy storage system" means commercially available technology that is capable of absorbing energy and storing it for a period of time for use at a later time, including, but not limited to, electrochemical, thermal, and electromechanical technologies, and may be interconnected behind the customer's meter or interconnected behind its own meter; and (ix) "future electrical requirements" means modeled electrical requirements upon occupation of a new or vacant property, and other reasonable expectations of future electrical use, as well as, for occupied properties, a reasonable approximation of the annual load of 2 electric vehicles and, for non-electric heating customers, a reasonable approximation of the incremental electric load associated with fuel switching. The approximations shall be applied to the appropriate net metering tariff and do not need to be unique to each individual eligible customer. The utility shall submit these approximations to the Commission for review, modification, and approval.

(c) A net metering facility shall be equipped with metering equipment that can measure the flow of electricity in both directions at the same rate.

(1) For eligible customers whose electric service has not been declared competitive pursuant to Section 16-113 of this Act as of July 1, 2011 and whose electric delivery service is provided and measured on a kilowatt-hour basis and electric supply service is not provided based on hourly pricing, this shall typically be accomplished through use of a single, bi-directional meter. If the eligible customer's existing electric revenue meter does not meet this requirement, the electricity provider shall arrange for the local electric utility or a meter service provider to install and maintain a new revenue meter at the electricity provider's expense, which may be the smart meter described by subsection (b) of Section 16-108.5 of this Act.

(2) For eligible customers whose electric service has not been declared competitive pursuant to Section 16-113 of this Act as of July 1, 2011 and whose electric delivery service is provided and measured on a kilowatt demand basis and electric supply service is not provided based on hourly pricing, this shall typically be accomplished through use of a dual channel meter capable of measuring the flow of electricity both into and out of the customer's facility at the same rate and ratio. If such customer's existing electric revenue meter does not meet this requirement, then the electricity provider shall arrange for the local electric utility or a meter service provider to install and maintain a new revenue meter at the electricity provider's expense, which may be the smart meter described by subsection (b) of Section 16-108.5 of this Act.

(3) For all other eligible customers, until such time as the local electric utility installs a smart meter, as described by subsection (b) of Section 16-108.5 of this Act, the electricity provider may arrange for the local electric utility or a meter service provider to install and maintain metering equipment capable of measuring the flow of electricity both into and out of the customer's facility at the same rate and ratio, typically through the use of a dual channel meter. If the eligible customer's existing electric revenue meter does not meet this requirement, then the costs of installing such equipment shall be paid for by the customer.

(d) An electricity provider shall measure and charge or credit for the net electricity supplied to eligible customers or provided by eligible customers whose electric service has not been declared competitive pursuant to Section 16-113 of this Act as of July 1, 2011 and whose electric delivery service is provided and measured on a kilowatt-hour basis and electric supply service is not provided based on hourly pricing in the following manner:

(1) If the amount of electricity used by the customer during the billing period exceeds the amount of electricity produced by the customer, the electricity provider shall charge the customer for the net electricity supplied to and used by the customer as provided in subsection (e-5) of this Section.

(2) If the amount of electricity produced by a customer during the billing period exceeds the amount of electricity used by the customer during that billing period, the electricity provider supplying that customer shall apply a 1:1 kilowatt-hour credit to a subsequent bill for service to the customer for the net electricity supplied to the electricity provider. The electricity provider shall continue to carry over any excess kilowatt-hour credits earned and apply those credits to subsequent billing periods to offset any customer-generator consumption in those billing periods until all credits are used or until the end of the annualized period.

(3) At the end of the year or annualized over the period that service is supplied by means of net metering, or in the event that the retail customer terminates service with the electricity provider prior to the end of the year or the annualized period, any remaining credits in the customer's account shall expire.

(d-5) An electricity provider shall measure and charge or credit for the net electricity supplied to eligible customers or provided by eligible customers whose electric service has not been declared competitive pursuant to Section 16-113 of this Act as of July 1, 2011 and whose electric delivery service is provided and measured on a kilowatt-hour basis and electric supply service is provided based on hourly pricing or time-of-use rates in the following manner:

(1) If the amount of electricity used by the customer during any hourly period or time-of-use period exceeds the amount of electricity produced by the customer, the electricity provider shall charge the customer for the net electricity supplied to and used by the customer according to the terms of the contract or tariff to which the same customer would be assigned to or be eligible for if the customer was not a net metering customer.

(2) If the amount of electricity produced by a customer during any hourly period or time-of-use period exceeds the amount of electricity used by the customer during that hourly period or time-of-use period, the energy provider shall apply a credit for the net kilowatt-hours produced in such period. The credit shall consist of an energy credit and a delivery service credit. The energy credit shall be valued at the same price per kilowatt-hour as the electric service provider would charge for kilowatt-hour energy sales during that same hourly period or time-of-use period. The delivery credit shall be equal to the net kilowatt-hours produced in such hourly period or time-of-use period times a credit that reflects all kilowatt-hour based charges in the customer's electric service rate, excluding energy charges.

(e) An electricity provider shall measure and charge or credit for the net electricity supplied to eligible customers whose electric service has not been declared competitive pursuant to Section 16-113 of this Act as of July 1, 2011 and whose electric delivery service is provided and measured on a kilowatt demand basis and electric supply service is not provided based on hourly pricing in the following manner:

(1) If the amount of electricity used by the customer during the billing period exceeds the amount of electricity produced by the customer, then the electricity provider shall charge the customer for the net electricity supplied to and used by the customer as provided in subsection (e-5) of this Section. The customer shall remain responsible for all taxes, fees, and utility delivery charges that would otherwise be applicable to the net amount of electricity used by the customer.

(2) If the amount of electricity produced by a customer during the billing period exceeds the amount of electricity used by the customer during that billing period, then the electricity provider supplying that customer shall apply a 1:1 kilowatt-hour credit that reflects the kilowatt-hour based charges in the customer's electric service rate to a subsequent bill for service to the customer for the net electricity supplied to the electricity provider. The electricity provider shall continue to carry over any excess kilowatt-hour credits earned and apply those credits to subsequent billing periods to offset any customer-generator consumption in those billing periods until all credits are used or until the end of the annualized period.

(3) At the end of the year or annualized over the period that service is supplied by means of net metering, or in the event that the retail customer terminates service with the electricity provider prior to the end of the year or the annualized period, any remaining credits in the customer's account shall expire.

(e-5) An electricity provider shall provide electric service to eligible customers who utilize net metering at non-discriminatory rates that are identical, with respect to rate structure, retail rate components, and any monthly charges, to the rates that the customer would be charged if not a net metering customer. An electricity provider shall not charge net metering customers any fee or charge or require additional equipment, insurance, or any other requirements not specifically authorized by interconnection standards authorized by the Commission, unless the fee, charge, or other requirement would apply to other similarly situated customers who are not net metering customers. The customer will remain responsible for all taxes, fees, and utility delivery charges that would otherwise be applicable to the net amount of electricity used by the customer. Subsections (c) through (e) of this Section shall not be construed to prevent an arms-length agreement between an electricity provider and an eligible customer that sets forth different prices, terms, and conditions for the provision of net metering service, including, but not limited to, the provision of the appropriate metering equipment for non-residential customers.

(f) Notwithstanding the requirements of subsections (c) through (e-5) of this Section, an electricity provider must require dual-channel metering for customers operating eligible renewable electrical generating facilities to whom the provisions of neither subsection (d), (d-5), nor (e) of this Section apply. In such cases, electricity charges and credits shall be determined as follows:

(1) The electricity provider shall assess and the customer remains responsible for all taxes, fees, and utility delivery charges that would otherwise be applicable to the gross amount of kilowatt-hours supplied to the eligible customer by the electricity provider.

(2) Each month that service is supplied by means of dual-channel metering, the electricity provider shall compensate the eligible customer for any excess kilowatt-hour credits at the electricity provider's avoided cost of electricity supply over the monthly period or as otherwise specified by the terms of a power-purchase agreement negotiated between the customer and electricity provider.

(3) For all eligible net metering customers taking service from an electricity provider under contracts or tariffs employing hourly or time-of-use rates, any monthly consumption of electricity shall be calculated according to the terms of the contract or tariff to which the same customer would be assigned to or be eligible for if the customer was not a net metering customer. When those same customer-generators are net generators during any discrete hourly or time-of-use period, the net kilowatt-hours produced shall be valued at the same price per kilowatt-hour as the electric service provider would charge for retail kilowatt-hour sales during that same time-of-use period.

(g) For purposes of federal and State laws providing renewable energy credits or greenhouse gas credits, the eligible customer shall be treated as owning and having title to the renewable energy attributes, renewable energy credits, and greenhouse gas emission credits related to any electricity produced by the qualified generating unit. The electricity provider may not condition participation in a net metering program on the signing over of a customer's renewable energy credits; provided, however, this subsection (g) shall not be construed to prevent an arms-length agreement between an electricity provider and an eligible customer that sets forth the ownership or title of the credits.

(h) Within 120 days after the effective date of this amendatory Act of the 95th General Assembly, the Commission shall establish standards for net metering and, if the Commission has not already acted on its own initiative, standards for the interconnection of eligible renewable generating equipment to the utility system. The interconnection standards shall address any procedural barriers, delays, and administrative costs associated with the interconnection of customer-generation while ensuring the safety and reliability of the units and the electric utility system. The Commission shall consider the Institute of Electrical and Electronics Engineers (IEEE) Standard 1547 and the issues of (i) reasonable and fair fees and costs, (ii) clear timelines for major milestones in the interconnection process, (iii) nondiscriminatory terms of agreement, and (iv) any best practices for interconnection of distributed generation.

(h-5) Within 90 days after the effective date of this amendatory Act of the 102nd General Assembly, the Commission shall:

(1) establish an Interconnection Working Group. The working group shall include representatives from electric utilities, developers of renewable electric generating facilities, other industries that regularly apply for interconnection with the electric utilities, representatives of distributed generation customers, the Commission Staff, and such other stakeholders with a substantial interest in the topics addressed by the Interconnection Working Group. The Interconnection Working Group shall address at least the following issues:

(A) cost and best available technology for interconnection and metering, including the standardization and publication of standard costs;

(B) transparency, accuracy and use of the distribution interconnection queue and hosting capacity maps;

(C) distribution system upgrade cost avoidance through use of advanced inverter functions;

(D) predictability of the queue management process and enforcement of timelines;

(E) benefits and challenges associated with group studies and cost sharing;

(F) minimum requirements for application to the interconnection process and throughout the interconnection process to avoid queue clogging behavior;

(G) process and customer service for interconnecting customers adopting distributed energy resources, including energy storage;

(H) options for metering distributed energy resources, including energy storage;

(I) interconnection of new technologies, including smart inverters and energy storage;

(J) collect, share, and examine data on Level 1 interconnection costs, including cost and type of upgrades required for interconnection, and use this data to inform the final standardized cost of Level 1 interconnection; and

(K) such other technical, policy, and tariff issues related to and affecting interconnection performance and customer service as determined by the Interconnection Working Group.

The Commission may create subcommittees of the Interconnection Working Group to focus on specific issues of importance, as appropriate. The Interconnection Working Group shall report to the Commission on recommended improvements to interconnection rules and tariffs and policies as determined by the Interconnection Working Group at least every 6 months. Such reports shall include consensus recommendations of the Interconnection Working Group and, if applicable, additional recommendations for which consensus was not reached. The Commission shall use the report from the Interconnection Working Group to determine whether processes should be commenced to formally codify or implement the recommendations;

(2) create or contract for an Ombudsman to resolve interconnection disputes through non-binding arbitration. The Ombudsman may be paid in full or in part through fees levied on the initiators of the dispute; and

(3) determine a single standardized cost for Level 1 interconnections, which shall not exceed $200.

(i) All electricity providers shall begin to offer net metering no later than April 1, 2008.

(j) An electricity provider shall provide net metering to eligible customers according to subsections (d), (d-5), and (e). Eligible renewable electrical generating facilities for which eligible customers registered for net metering before January 1, 2025 shall continue to receive net metering services according to subsections (d), (d-5), and (e) of this Section for the lifetime of the system, regardless of whether those retail customers change electricity providers or whether the retail customer benefiting from the system changes. On and after January 1, 2025, any eligible customer that applies for net metering and previously would have qualified under subsections (d), (d-5), or (e) shall only be eligible for net metering as described in subsection (n).

(k) Each electricity provider shall maintain records and report annually to the Commission the total number of net metering customers served by the provider, as well as the type, capacity, and energy sources of the generating systems used by the net metering customers. Nothing in this Section shall limit the ability of an electricity provider to request the redaction of information deemed by the Commission to be confidential business information.

(l)(1) Notwithstanding the definition of "eligible customer" in item (ii) of subsection (b) of this Section, each electricity provider shall allow net metering as set forth in this subsection (l) and for the following projects, provided that only electric utilities serving more than 200,000 customers as of January 1, 2021 shall provide net metering for projects that are eligible for subparagraph (C) of this paragraph (1) and have energized after the effective date of this amendatory Act of the 102nd General Assembly:

(A) properties owned or leased by multiple customers that contribute to the operation of an eligible renewable electrical generating facility through an ownership or leasehold interest of at least 200 watts in such facility, such as a community-owned wind project, a community-owned biomass project, a community-owned solar project, or a community methane digester processing livestock waste from multiple sources, provided that the facility is also located within the utility's service territory;

(B) individual units, apartments, or properties located in a single building that are owned or leased by multiple customers and collectively served by a common eligible renewable electrical generating facility, such as an office or apartment building, a shopping center or strip mall served by photovoltaic panels on the roof; and

(C) subscriptions to community renewable generation projects, including community renewable generation projects on the customer's side of the billing meter of a host facility and partially used for the customer's own load.

In addition, the nameplate capacity of the eligible renewable electric generating facility that serves the demand of the properties, units, or apartments identified in paragraphs (1) and (2) of this subsection (l) shall not exceed 5,000 kilowatts in nameplate capacity in total. Any eligible renewable electrical generating facility or community renewable generation project that is powered by photovoltaic electric energy and installed after the effective date of this amendatory Act of the 99th General Assembly must be installed by a qualified person in compliance with the requirements of Section 16-128A of the Public Utilities Act and any rules or regulations adopted thereunder.

(2) Notwithstanding anything to the contrary, an electricity provider shall provide credits for the electricity produced by the projects described in paragraph (1) of this subsection (l). The electricity provider shall provide credits that include at least energy supply, capacity, transmission, and, if applicable, the purchased energy adjustment on the subscriber's monthly bill equal to the subscriber's share of the production of electricity from the project, as determined by paragraph (3) of this subsection (l). For customers with transmission or capacity charges not charged on a kilowatt-hour basis, the electricity provider shall prepare a reasonable approximation of the kilowatt-hour equivalent value and provide that value as a monetary credit. The electricity provider shall submit these approximation methodologies to the Commission for review, modification, and approval. Notwithstanding anything to the contrary, customers on payment plans or participating in budget billing programs shall have credits applied on a monthly basis.

(3) Notwithstanding anything to the contrary and regardless of whether a subscriber to an eligible community renewable generation project receives power and energy service from the electric utility or an alternative retail electric supplier, for projects eligible under paragraph (C) of subparagraph (1) of this subsection (l), electric utilities serving more than 200,000 customers as of January 1, 2021 shall provide the monetary credits to a subscriber's subsequent bill for the electricity produced by community renewable generation projects. The electric utility shall provide monetary credits to a subscriber's subsequent bill at the utility's total price to compare equal to the subscriber's share of the production of electricity from the project, as determined by paragraph (5) of this subsection (l). For the purposes of this subsection, "total price to compare" means the rate or rates published by the Illinois Commerce Commission for energy supply for eligible customers receiving supply service from the electric utility, and shall include energy, capacity, transmission, and the purchased energy adjustment. Notwithstanding anything to the contrary, customers on payment plans or participating in budget billing programs shall have credits applied on a monthly basis. Any applicable credit or reduction in load obligation from the production of the community renewable generating projects receiving a credit under this subsection shall be credited to the electric utility to offset the cost of providing the credit. To the extent that the credit or load obligation reduction does not completely offset the cost of providing the credit to subscribers of community renewable generation projects as described in this subsection, the electric utility may recover the remaining costs through its Multi-Year Rate Plan. All electric utilities serving 200,000 or fewer customers as of January 1, 2021 shall only provide the monetary credits to a subscriber's subsequent bill for the electricity produced by community renewable generation projects if the subscriber receives power and energy service from the electric utility. Alternative retail electric suppliers providing power and energy service to a subscriber located within the service territory of an electric utility not subject to Sections 16-108.18 and 16-118 shall provide the monetary credits to the subscriber's subsequent bill for the electricity produced by community renewable generation projects.

(4) If requested by the owner or operator of a community renewable generating project, an electric utility serving more than 200,000 customers as of January 1, 2021 shall enter into a net crediting agreement with the owner or operator to include a subscriber's subscription fee on the subscriber's monthly electric bill and provide the subscriber with a net credit equivalent to the total bill credit value for that generation period minus the subscription fee, provided the subscription fee is structured as a fixed percentage of bill credit value. The net crediting agreement shall set forth payment terms from the electric utility to the owner or operator of the community renewable generating project, and the electric utility may charge a net crediting fee to the owner or operator of a community renewable generating project that may not exceed 2% of the bill credit value. Notwithstanding anything to the contrary, an electric utility serving 200,000 customers or fewer as of January 1, 2021 shall not be obligated to enter into a net crediting agreement with the owner or operator of a community renewable generating project.

(5) For the purposes of facilitating net metering, the owner or operator of the eligible renewable electrical generating facility or community renewable generation project shall be responsible for determining the amount of the credit that each customer or subscriber participating in a project under this subsection (l) is to receive in the following manner:

(A) The owner or operator shall, on a monthly basis, provide to the electric utility the kilowatthours of generation attributable to each of the utility's retail customers and subscribers participating in projects under this subsection (l) in accordance with the customer's or subscriber's share of the eligible renewable electric generating facility's or community renewable generation project's output of power and energy for such month. The owner or operator shall electronically transmit such calculations and associated documentation to the electric utility, in a format or method set forth in the applicable tariff, on a monthly basis so that the electric utility can reflect the monetary credits on customers' and subscribers' electric utility bills. The electric utility shall be permitted to revise its tariffs to implement the provisions of this amendatory Act of the 102nd General Assembly. The owner or operator shall separately provide the electric utility with the documentation detailing the calculations supporting the credit in the manner set forth in the applicable tariff.

(B) For those participating customers and subscribers who receive their energy supply from an alternative retail electric supplier, the electric utility shall remit to the applicable alternative retail electric supplier the information provided under subparagraph (A) of this paragraph (3) for such customers and subscribers in a manner set forth in such alternative retail electric supplier's net metering program, or as otherwise agreed between the utility and the alternative retail electric supplier. The alternative retail electric supplier shall then submit to the utility the amount of the charges for power and energy to be applied to such customers and subscribers, including the amount of the credit associated with net metering.

(C) A participating customer or subscriber may provide authorization as required by applicable law that directs the electric utility to submit information to the owner or operator of the eligible renewable electrical generating facility or community renewable generation project to which the customer or subscriber has an ownership or leasehold interest or a subscription. Such information shall be limited to the components of the net metering credit calculated under this subsection (l), including the bill credit rate, total kilowatthours, and total monetary credit value applied to the customer's or subscriber's bill for the monthly billing period.

(l-5) Within 90 days after the effective date of this amendatory Act of the 102nd General Assembly, each electric utility subject to this Section shall file a tariff or tariffs to implement the provisions of subsection (l) of this Section, which shall, consistent with the provisions of subsection (l), describe the terms and conditions under which owners or operators of qualifying properties, units, or apartments may participate in net metering. The Commission shall approve, or approve with modification, the tariff within 120 days after the effective date of this amendatory Act of the 102nd General Assembly.

(m) Nothing in this Section shall affect the right of an electricity provider to continue to provide, or the right of a retail customer to continue to receive service pursuant to a contract for electric service between the electricity provider and the retail customer in accordance with the prices, terms, and conditions provided for in that contract. Either the electricity provider or the customer may require compliance with the prices, terms, and conditions of the contract.

(n) On and after January 1, 2025, the net metering services described in subsections (d), (d-5), and (e) of this Section shall no longer be offered, except as to those eligible renewable electrical generating facilities for which retail customers are receiving net metering service under these subsections at the time the net metering services under those subsections are no longer offered; those systems shall continue to receive net metering services described in subsections (d), (d-5), and (e) of this Section for the lifetime of the system, regardless of if those retail customers change electricity providers or whether the retail customer benefiting from the system changes. The electric utility serving more than 200,000 customers as of January 1, 2021 is responsible for ensuring the billing credits continue without lapse for the lifetime of systems, as required in subsection (o). Those retail customers that begin taking net metering service after the date that net metering services are no longer offered under such subsections shall be subject to the provisions set forth in the following paragraphs (1) through (3) of this subsection (n):

(1) An electricity provider shall charge or credit for the net electricity supplied to eligible customers or provided by eligible customers whose electric supply service is not provided based on hourly pricing in the following manner:

(A) If the amount of electricity used by the customer during the monthly billing period exceeds the amount of electricity produced by the customer, then the electricity provider shall charge the customer for the net kilowatt-hour based electricity charges reflected in the customer's electric service rate supplied to and used by the customer as provided in paragraph (3) of this subsection (n).

(B) If the amount of electricity produced by a customer during the monthly billing period exceeds the amount of electricity used by the customer during that billing period, then the electricity provider supplying that customer shall apply a 1:1 kilowatt-hour energy or monetary credit kilowatt-hour supply charges to the customer's subsequent bill. The customer shall choose between 1:1 kilowatt-hour or monetary credit at the time of application. For the purposes of this subsection, "kilowatt-hour supply charges" means the kilowatt-hour equivalent values for energy, capacity, transmission, and the purchased energy adjustment, if applicable. Notwithstanding anything to the contrary, customers on payment plans or participating in budget billing programs shall have credits applied on a monthly basis. The electricity provider shall continue to carry over any excess kilowatt-hour or monetary energy credits earned and apply those credits to subsequent billing periods. For customers with transmission or capacity charges not charged on a kilowatt-hour basis, the electricity provider shall prepare a reasonable approximation of the kilowatt-hour equivalent value and provide that value as a monetary credit. The electricity provider shall submit these approximation methodologies to the Commission for review, modification, and approval.

(C) (Blank).

(2) An electricity provider shall charge or credit for the net electricity supplied to eligible customers or provided by eligible customers whose electric supply service is provided based on hourly pricing in the following manner:

(A) If the amount of electricity used by the customer during any hourly period exceeds the amount of electricity produced by the customer, then the electricity provider shall charge the customer for the net electricity supplied to and used by the customer as provided in paragraph (3) of this subsection (n).

(B) If the amount of electricity produced by a customer during any hourly period exceeds the amount of electricity used by the customer during that hourly period, the energy provider shall calculate an energy credit for the net kilowatt-hours produced in such period, and shall apply that credit as a monetary credit to the customer's subsequent bill. The value of the energy credit shall be calculated using the same price per kilowatt-hour as the electric service provider would charge for kilowatt-hour energy sales during that same hourly period and shall also include values for capacity and transmission. For customers with transmission or capacity charges not charged on a kilowatt-hour basis, the electricity provider shall prepare a reasonable approximation of the kilowatt-hour equivalent value and provide that value as a monetary credit. The electricity provider shall submit these approximation methodologies to the Commission for review, modification, and approval. Notwithstanding anything to the contrary, customers on payment plans or participating in budget billing programs shall have credits applied on a monthly basis.

(3) An electricity provider shall provide electric service to eligible customers who utilize net metering at non-discriminatory rates that are identical, with respect to rate structure, retail rate components, and any monthly charges, to the rates that the customer would be charged if not a net metering customer. An electricity provider shall charge the customer for the net electricity supplied to and used by the customer according to the terms of the contract or tariff to which the same customer would be assigned or be eligible for if the customer was not a net metering customer. An electricity provider shall not charge net metering customers any fee or charge or require additional equipment, insurance, or any other requirements not specifically authorized by interconnection standards authorized by the Commission, unless the fee, charge, or other requirement would apply to other similarly situated customers who are not net metering customers. The customer remains responsible for the gross amount of delivery services charges, supply-related charges that are kilowatt based, and all taxes and fees related to such charges. The customer also remains responsible for all taxes and fees that would otherwise be applicable to the net amount of electricity used by the customer. Paragraphs (1) and (2) of this subsection (n) shall not be construed to prevent an arms-length agreement between an electricity provider and an eligible customer that sets forth different prices, terms, and conditions for the provision of net metering service, including, but not limited to, the provision of the appropriate metering equipment for non-residential customers. Nothing in this paragraph (3) shall be interpreted to mandate that a utility that is only required to provide delivery services to a given customer must also sell electricity to such customer.

(o) Within 90 days after the effective date of this amendatory Act of the 102nd General Assembly, each electric utility subject to this Section shall file a tariff, which shall, consistent with the provisions of this Section, propose the terms and conditions under which a customer may participate in net metering. The tariff for electric utilities serving more than 200,000 customers as of January 1, 2021 shall also provide a streamlined and transparent bill crediting system for net metering to be managed by the electric utilities. The terms and conditions shall include, but are not limited to, that an electric utility shall manage and maintain billing of net metering credits and charges regardless of if the eligible customer takes net metering under an electric utility or alternative retail electric supplier. The electric utility serving more than 200,000 customers as of January 1, 2021 shall process and approve all net metering applications, even if an eligible customer is served by an alternative retail electric supplier; and the utility shall forward application approval to the appropriate alternative retail electric supplier. Eligibility for net metering shall remain with the owner of the utility billing address such that, if an eligible renewable electrical generating facility changes ownership, the net metering eligibility transfers to the new owner. The electric utility serving more than 200,000 customers as of January 1, 2021 shall manage net metering billing for eligible customers to ensure full crediting occurs on electricity bills, including, but not limited to, ensuring net metering crediting begins upon commercial operation date, net metering billing transfers immediately if an eligible customer switches from an electric utility to alternative retail electric supplier or vice versa, and net metering billing transfers between ownership of a valid billing address. All transfers referenced in the preceding sentence shall include transfer of all banked credits. All electric utilities serving 200,000 or fewer customers as of January 1, 2021 shall manage net metering billing for eligible customers receiving power and energy service from the electric utility to ensure full crediting occurs on electricity bills, ensuring net metering crediting begins upon commercial operation date, net metering billing transfers immediately if an eligible customer switches from an electric utility to alternative retail electric supplier or vice versa, and net metering billing transfers between ownership of a valid billing address. Alternative retail electric suppliers providing power and energy service to eligible customers located within the service territory of an electric utility serving 200,000 or fewer customers as of January 1, 2021 shall manage net metering billing for eligible customers to ensure full crediting occurs on electricity bills, including, but not limited to, ensuring net metering crediting begins upon commercial operation date, net metering billing transfers immediately if an eligible customer switches from an electric utility to alternative retail electric supplier or vice versa, and net metering billing transfers between ownership of a valid billing address.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-107.6)

Sec. 16-107.6. Distributed generation rebate.

(a) In this Section:

"Additive services" means the services that distributed energy resources provide to the energy system and society that are not (1) already included in the base rebates for system-wide grid services; or (2) otherwise already compensated. Additive services may reflect, but shall not be limited to, any geographic, time-based, performance-based, and other benefits of distributed energy resources, as well as the present and future technological capabilities of distributed energy resources and present and future grid needs.

"Distributed energy resource" means a wide range of technologies that are located on the customer side of the customer's electric meter, including, but not limited to, distributed generation, energy storage, electric vehicles, and demand response technologies.

"Energy storage system" means commercially available technology that is capable of absorbing energy and storing it for a period of time for use at a later time, including, but not limited to, electrochemical, thermal, and electromechanical technologies, and may be interconnected behind the customer's meter or interconnected behind its own meter.

"Smart inverter" means a device that converts direct current into alternating current and meets the IEEE 1547-2018 equipment standards. Until devices that meet the IEEE 1547-2018 standard are available, devices that meet the UL 1741 SA standard are acceptable.

"Subscriber" has the meaning set forth in Section 1-10 of the Illinois Power Agency Act.

"Subscription" has the meaning set forth in Section 1-10 of the Illinois Power Agency Act.

"System-wide grid services" means the benefits that a distributed energy resource provides to the distribution grid for a period of no less than 25 years. System-wide grid services do not vary by location, time, or the performance characteristics of the distributed energy resource. System-wide grid services include, but are not limited to, avoided or deferred distribution capacity costs, resilience and reliability benefits, avoided or deferred distribution operation and maintenance costs, distribution voltage and power quality benefits, and line loss reductions.

"Threshold date" means December 31, 2024 or the date on which the utility's tariff or tariffs setting the new compensation values established under subsection (e) take effect, whichever is later.

(b) An electric utility that serves more than 200,000 customers in the State shall file a petition with the Commission requesting approval of the utility's tariff to provide a rebate to the owner or operator of distributed generation, including third-party owned systems, that meets the following criteria:

(1) has a nameplate generating capacity no greater than 5,000 kilowatts and is primarily used to offset a customer's electricity load;

(2) is located on the customer's side of the billing meter and for the customer's own use;

(3) is interconnected to electric distribution facilities owned by the electric utility under rules adopted by the Commission by means of the inverter or smart inverter required by this Section, as applicable.

For purposes of this Section, "distributed generation" shall satisfy the definition of distributed renewable energy generation device set forth in Section 1-10 of the Illinois Power Agency Act to the extent such definition is consistent with the requirements of this Section.

In addition, any new photovoltaic distributed generation that is installed after June 1, 2017 (the effective date of Public Act 99-906) must be installed by a qualified person, as defined by subsection (i) of Section 1-56 of the Illinois Power Agency Act.

The tariff shall include a base rebate that compensates distributed generation for the system-wide grid services associated with distributed generation and, after the proceeding described in subsection (e) of this Section, an additional payment or payments for the additive services. The tariff shall provide that the smart inverter associated with the distributed generation shall provide autonomous response to grid conditions through its default settings as approved by the Commission. Default settings may not be changed after the execution of the interconnection agreement except by mutual agreement between the utility and the owner or operator of the distributed generation. Nothing in this Section shall negate or supersede Institute of Electrical and Electronics Engineers equipment standards or other similar standards or requirements. The tariff shall not limit the ability of the smart inverter or other distributed energy resource to provide wholesale market products such as regulation, demand response, or other services, or limit the ability of the owner of the smart inverter or the other distributed energy resource to receive compensation for providing those wholesale market products or services.

(b-5) Within 30 days after the effective date of this amendatory Act of the 102nd General Assembly, each electric public utility with 3,000,000 or more retail customers shall file a tariff with the Commission that further compensates any retail customer that installs or has installed photovoltaic facilities paired with energy storage facilities on or adjacent to its premises for the benefits the facilities provide to the distribution grid. The tariff shall provide that, in addition to the other rebates identified in this Section, the electric utility shall rebate to such retail customer (i) the previously incurred and future costs of installing interconnection facilities and related infrastructure to enable full participation in the PJM Interconnection, LLC or its successor organization frequency regulation market; and (ii) all wholesale demand charges incurred after the effective date of this amendatory Act of the 102nd General Assembly. The Commission shall approve, or approve with modification, the tariff within 120 days after the utility's filing.

(c) The proposed tariff authorized by subsection (b) of this Section shall include the following participation terms for rebates to be applied under this Section for distributed generation that satisfies the criteria set forth in subsection (b) of this Section:

(1) The owner or operator of distributed generation that services customers not eligible for net metering under subsection (d), (d-5), or (e) of Section 16-107.5 of this Act may apply for a rebate as provided for in this Section. Until the threshold date, the value of the rebate shall be $250 per kilowatt of nameplate generating capacity, measured as nominal DC power output, of that customer's distributed generation. To the extent the distributed generation also has an associated energy storage, then the energy storage system shall be separately compensated with a base rebate of $250 per kilowatt-hour of nameplate capacity. Any distributed generation device that is compensated for storage in this subsection (1) before the threshold date shall participate in one or more programs determined through the Multi-Year Integrated Grid Planning process that are designed to meet peak reduction and flexibility. After the threshold date, the value of the base rebate and additional compensation for any additive services shall be as determined by the Commission in the proceeding described in subsection (e) of this Section, provided that the value of the base rebate for system-wide grid services shall not be lower than $250 per kilowatt of nameplate generating capacity of distributed generation or community renewable generation project.

(2) The owner or operator of distributed generation that, before the threshold date, would have been eligible for net metering under subsection (d), (d-5), or (e) of Section 16-107.5 of this Act and that has not previously received a distributed generation rebate, may apply for a rebate as provided for in this Section. Until the threshold date, the value of the base rebate shall be $300 per kilowatt of nameplate generating capacity, measured as nominal DC power output, of the distributed generation. The owner or operator of distributed generation that, before the threshold date, is eligible for net metering under subsection (d), (d-5), or (e) of Section 16-107.5 of this Act may apply for a base rebate for an energy storage device that uses the same smart inverter as the distributed generation, regardless of whether the distributed generation applies for a rebate for the distributed generation device. The energy storage system shall be separately compensated at a base payment of $300 per kilowatt-hour of nameplate capacity. Any distributed generation device that is compensated for storage in this subsection (2) before the threshold date shall participate in a peak time rebate program, hourly pricing program, or time-of-use rate program offered by the applicable electric utility. After the threshold date, the value of the base rebate and additional compensation for any additive services shall be as determined by the Commission in the proceeding described in subsection (e) of this Section, provided that, prior to December 31, 2029, the value of the base rebate for system-wide services shall not be lower than $300 per kilowatt of nameplate generating capacity of distributed generation, after which it shall not be lower than $250 per kilowatt of nameplate capacity.

(3) Upon approval of a rebate application submitted under this subsection (c), the retail customer shall no longer be entitled to receive any delivery service credits for the excess electricity generated by its facility and shall be subject to the provisions of subsection (n) of Section 16-107.5 of this Act unless the owner or operator receives a rebate only for an energy storage device and not for the distributed generation device.

(4) To be eligible for a rebate described in this subsection (c), the owner or operator of the distributed generation must have a smart inverter installed and in operation on the distributed generation.

(d) The Commission shall review the proposed tariff authorized by subsection (b) of this Section and may make changes to the tariff that are consistent with this Section and with the Commission's authority under Article IX of this Act, subject to notice and hearing. Following notice and hearing, the Commission shall issue an order approving, or approving with modification, such tariff no later than 240 days after the utility files its tariff. Upon the effective date of this amendatory Act of the 102nd General Assembly, an electric utility shall file a petition with the Commission to amend and update any existing tariffs to comply with subsections (b) and (c).

(e) By no later than June 30, 2023, the Commission shall open an independent, statewide investigation into the value of, and compensation for, distributed energy resources. The Commission shall conduct the investigation, but may arrange for experts or consultants independent of the utilities and selected by the Commission to assist with the investigation. The cost of the investigation shall be shared by the utilities filing tariffs under subsection (b) of this Section but may be recovered as an expense through normal ratemaking procedures.

(1) The Commission shall ensure that the investigation includes, at minimum, diverse sets of stakeholders; a review of best practices in calculating the value of distributed energy resource benefits; a review of the full value of the distributed energy resources and the manner in which each component of that value is or is not otherwise compensated; and assessments of how the value of distributed energy resources may evolve based on the present and future technological capabilities of distributed energy resources and based on present and future grid needs.

(2) The Commission's final order concluding this investigation shall establish an annual process and formula for the compensation of distributed generation and energy storage systems, and an initial set of inputs for that formula. The Commission's final order concluding this investigation shall establish base rebates that compensate distributed generation, community renewable generation projects and energy storage systems for the system-wide grid services that they provide. Those base rebate values shall be consistent across the state, and shall not vary by customer, customer class, customer location, or any other variable. With respect to rebates for distributed generation or community renewable generation projects, that rebate shall not be lower than $250 per kilowatt of nameplate generating capacity of the distributed generation or community renewable generation project. The Commission's final order concluding this proceeding shall also direct the utilities to update the formula, on an annual basis, with inputs derived from their integrated grid plans developed pursuant to Section 16-105.17. The base rebate shall be updated annually based on the annual updates to the formula inputs, but, with respect to rebates for distributed generation or community renewable generation projects, shall be no lower than $250 per kilowatt of nameplate generating capacity of the distributed generation or community renewable generation project.

(3) The Commission shall also determine, as a part of its investigation under this subsection, whether distributed energy resources can provide any additive services. Those additive services may include services that are provided through utility-controlled responses to grid conditions. If the Commission determines that distributed energy resources can provide additive grid services, the Commission shall determine the terms and conditions for the operation and compensation of those services. That compensation shall be above and beyond the base rebate that the distributed energy generation, community renewable generation project and energy storage system receives. Compensation for additive services may vary by location, time, performance characteristics, technology types, or other variables.

(4) The Commission shall ensure that compensation for distributed energy resources, including base rebates and any payments for additive services, shall reflect all reasonably known and measurable values of the distributed generation over its full expected useful life. Compensation for additive services shall reflect, but shall not be limited to, any geographic, time-based, performance-based, and other benefits of distributed generation, as well as the present and future technological capabilities of distributed energy resources and present and future grid needs.

(5) The Commission shall consider the electric utility's integrated grid plan developed pursuant to Section 16-105.17 of this Act to help identify the value of distributed energy resources for the purpose of calculating the compensation described in this subsection.

(6) The Commission shall determine additional compensation for distributed energy resources that creates savings and value on the distribution system by being co-located or in close proximity to electric vehicle charging infrastructure in use by medium-duty and heavy-duty vehicles, primarily serving environmental justice communities, as outlined in the utility integrated grid planning process under Section 16-105.17 of this Act.

No later than 60 days after the Commission enters its final order under this subsection (e), each utility shall file its updated tariff or tariffs in compliance with the order, including new tariffs for the recovery of costs incurred under this subsection (e) that shall provide for volumetric-based cost recovery, and the Commission shall approve, or approve with modification, the tariff or tariffs within 240 days after the utility's filing.

(f) Notwithstanding any provision of this Act to the contrary, the owner or operator of a community renewable generation project as defined in Section 1-10 of the Illinois Power Agency Act shall also be eligible to apply for the rebate described in this Section. The owner or operator of the community renewable generation project may apply for a rebate only if the owner or operator, or previous owner or operator, of the community renewable generation project has not already submitted an application, and, regardless of whether the subscriber is a residential or non-residential customer, may be allowed the amount identified in paragraph (1) of subsection (c) applicable on the date that the application is submitted.

(g) The owner of the distributed generation or community renewable generation project may apply for the rebate or rebates approved under this Section at the time of execution of an interconnection agreement with the distribution utility and shall receive the value available at that time of execution of the interconnection agreement, provided the project reaches mechanical completion within 24 months after execution of the interconnection agreement. If the project has not reached mechanical completion within 24 months after execution, the owner may reapply for the rebate or rebates approved under this Section available at the time of application and shall receive the value available at the time of application. The utility shall issue the rebate no later than 60 days after the project is energized. In the event the application is incomplete or the utility is otherwise unable to calculate the payment based on the information provided by the owner, the utility shall issue the payment no later than 60 days after the application is complete or all requested information is received.

(h) An electric utility shall recover from its retail customers all of the costs of the rebates made under a tariff or tariffs approved under subsection (d) of this Section, including, but not limited to, the value of the rebates and all costs incurred by the utility to comply with and implement subsections (b) and (c) of this Section, but not including costs incurred by the utility to comply with and implement subsection (e) of this Section, consistent with the following provisions:

(1) The utility shall defer the full amount of its costs as a regulatory asset. The total costs deferred as a regulatory asset shall be amortized over a 15-year period. The unamortized balance shall be recognized as of December 31 for a given year. The utility shall also earn a return on the total of the unamortized balance of the regulatory assets, less any deferred taxes related to the unamortized balance, at an annual rate equal to the utility's weighted average cost of capital that includes, based on a year-end capital structure, the utility's actual cost of debt for the applicable calendar year and a cost of equity, which shall be calculated as the sum of (i) the average for the applicable calendar year of the monthly average yields of 30-year U.S. Treasury bonds published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication; and (ii) 580 basis points, including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return.

When an electric utility creates a regulatory asset under the provisions of this paragraph (1) of subsection (h), the costs are recovered over a period during which customers also receive a benefit, which is in the public interest. Accordingly, it is the intent of the General Assembly that an electric utility that elects to create a regulatory asset under the provisions of this paragraph (1) shall recover all of the associated costs, including, but not limited to, its cost of capital as set forth in this paragraph (1). After the Commission has approved the prudence and reasonableness of the costs that comprise the regulatory asset, the electric utility shall be permitted to recover all such costs, and the value and recoverability through rates of the associated regulatory asset shall not be limited, altered, impaired, or reduced. To enable the financing of the incremental capital expenditures, including regulatory assets, for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State, the utility's actual year-end capital structure that includes a common equity ratio, excluding goodwill, of up to and including 50% of the total capital structure shall be deemed reasonable and used to set rates.

(2) The utility, at its election, may recover all of the costs as part of a filing for a general increase in rates under Article IX of this Act, as part of an annual filing to update a performance-based formula rate under subsection (d) of Section 16-108.5 of this Act, or through an automatic adjustment clause tariff, provided that nothing in this paragraph (2) permits the double recovery of such costs from customers. If the utility elects to recover the costs it incurs under subsections (b) and (c) through an automatic adjustment clause tariff, the utility may file its proposed tariff together with the tariff it files under subsection (b) of this Section or at a later time. The proposed tariff shall provide for an annual reconciliation, less any deferred taxes related to the reconciliation, with interest at an annual rate of return equal to the utility's weighted average cost of capital as calculated under paragraph (1) of this subsection (h), including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return, of the revenue requirement reflected in rates for each calendar year, beginning with the calendar year in which the utility files its automatic adjustment clause tariff under this subsection (h), with what the revenue requirement would have been had the actual cost information for the applicable calendar year been available at the filing date. The Commission shall review the proposed tariff and may make changes to the tariff that are consistent with this Section and with the Commission's authority under Article IX of this Act, subject to notice and hearing. Following notice and hearing, the Commission shall issue an order approving, or approving with modification, such tariff no later than 240 days after the utility files its tariff.

(i) An electric utility shall recover from its retail customers, on a volumetric basis, all of the costs of the rebates made under a tariff or tariffs placed into effect under subsection (e) of this Section, including, but not limited to, the value of the rebates and all costs incurred by the utility to comply with and implement subsection (e) of this Section, consistent with the following provisions:

(1) The utility may defer a portion of its costs as a regulatory asset. The Commission shall determine the portion that may be appropriately deferred as a regulatory asset. Factors that the Commission shall consider in determining the portion of costs that shall be deferred as a regulatory asset include, but are not limited to: (i) whether and the extent to which a cost effectively deferred or avoided other distribution system operating costs or capital expenditures; (ii) the extent to which a cost provides environmental benefits; (iii) the extent to which a cost improves system reliability or resilience; (iv) the electric utility's distribution system plan developed pursuant to Section 16-105.17 of this Act; (v) the extent to which a cost advances equity principles; and (vi) such other factors as the Commission deems appropriate. The remainder of costs shall be deemed an operating expense and shall be recoverable if found prudent and reasonable by the Commission.

The total costs deferred as a regulatory asset shall be amortized over a 15-year period. The unamortized balance shall be recognized as of December 31 for a given year. The utility shall also earn a return on the total of the unamortized balance of the regulatory assets, less any deferred taxes related to the unamortized balance, at an annual rate equal to the utility's weighted average cost of capital that includes, based on a year-end capital structure, the utility's actual cost of debt for the applicable calendar year and a cost of equity, which shall be calculated as the sum of: (I) the average for the applicable calendar year of the monthly average yields of 30-year U.S. Treasury bonds published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication; and (II) 580 basis points, including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return.

(2) The utility may recover all of the costs through an automatic adjustment clause tariff, on a volumetric basis. The utility may file its proposed cost-recovery tariff together with the tariff it files under subsection (e) of this Section or at a later time. The proposed tariff shall provide for an annual reconciliation, less any deferred taxes related to the reconciliation, with interest at an annual rate of return equal to the utility's weighted average cost of capital as calculated under paragraph (1) of this subsection (i), including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return, of the revenue requirement reflected in rates for each calendar year, beginning with the calendar year in which the utility files its automatic adjustment clause tariff under this subsection (i), with what the revenue requirement would have been had the actual cost information for the applicable calendar year been available at the filing date. The Commission shall review the proposed tariff and may make changes to the tariff that are consistent with this Section and with the Commission's authority under Article IX of this Act, subject to notice and hearing. Following notice and hearing, the Commission shall issue an order approving, or approving with modification, such tariff no later than 240 days after the utility files its tariff.

(j) No later than 90 days after the Commission enters an order, or order on rehearing, whichever is later, approving an electric utility's proposed tariff under this Section, the electric utility shall provide notice of the availability of rebates under this Section.

(Source: P.A. 102-662, eff. 9-15-21; 102-1031, eff. 5-27-22.)

(220 ILCS 5/16-107.7)

Sec. 16-107.7. Power price mitigation rebate.

(a) Illinois electric utility customers have been impacted by unanticipated changes to electric power and capacity prices during a period of economic hardship associated with recent global events, including increasing gas prices due to the Russian invasion of Ukraine and the COVID-19 pandemic. The recent power and capacity procurement events affect the market prices paid by customers. Accordingly, as many customers have experienced increased electric utility bill impacts due to the increase in electric power and capacity prices, it is the policy of the State to assist qualifying customers through a power price mitigation rebate for the June 2023 through October 2024 electric utility billing cycle. As used in this Section, "small commercial customer" means those nonresidential retail customers of an electric utility consuming 15,000 kilowatt-hours or less of electricity annually in its service area whose service has not yet been declared competitive pursuant to Section 16-113.

(b) Any electric utility serving adversely impacted residential and small commercial customers shall notify the Commission by April 15, 2023 of the same and provide the results of the calculations set forth in this subsection. As used in this Section, "electric utility serving adversely impacted residential and small commercial customers" means any electric utility that can demonstrate that the utility default power supply rate procured from the Illinois Power Agency and available to its residential and small commercial customers has experienced, or will experience, a more than 90% year-over-year total supply charge increase, as calculated by comparing the total supply charge effective on June 1, 2021, as reported by the electric utility to the Commission pursuant to subsection (i) of Section 16-111.5, and the total supply charge effective on June 1, 2022, as reported to the Commission pursuant to subsection (i) of Section 16-111.5. The total supply charge effective on June 1, 2021, and June 1, 2022, respectively, as reported pursuant to subsection (i) of Section 16-111.5, shall be used to calculate an electric utility's qualification under this Section and no other adjustments shall be made for purposes of the calculation, including, but not limited to, any transmission costs, purchased electricity adjustments, or any other credits. Any small multijurisdictional electric utility that relies upon company-owned generation resources, including fossil fueled generation, to supply the majority of its eligible State retail customers' energy and capacity needs shall be ineligible to file a notice or receive funding for rebate credits pursuant to this Section. The Commission shall have 5 days from the date of receipt of the utility's notice to review the calculations and notify the electric utility as to whether it qualifies as an electric utility serving adversely impacted residential and small commercial customers under this Section.

(c) Any electric utility that provides notice to the Commission of qualification under subsection (b) shall concurrently file a tariff with the Commission that provides for a monthly rebate credit to be given to all residential and small commercial customers, beginning as soon as is practicable following the effective date of this amendatory Act of the 102nd General Assembly. The tariff shall provide that the total funds appropriated by the Department of Commerce and Economic Opportunity shall be divided equally and issued to all of its active residential and small commercial customers, including customers that take supply service from alternative retail suppliers or real-time pricing tariffs. The tariff shall further provide that the monthly rebate credit will be reflected on, and applied to, customer bills beginning at the start of a monthly billing period and continue through the October 2023 billing period in a manner compliant with subsections (d) and (e). The tariff shall also provide that the utility may apply the monthly rebate credit to up to 5 monthly billing periods ending in October 2023, and the utility may aggregate monthly rebate credits. To the extent a rebate credit is greater than a customer's bill in a given month, the excess rebate credit amount shall apply to the next billing period, even if the billing period is after October 2023, until the customer's rebate credit has been fully applied.

(d) The Commission shall have 5 days from the date an electric utility files the tariff pursuant to subsection (c) to review the tariff for compliance with this Section, and, subject to appropriation to the Department of Commerce and Economic Opportunity for purposes of the power price mitigation, the tariff shall go into effect no later than 7 days from the original tariff filing date or one day from the date of any compliance filing, whichever is later. Upon the tariff becoming effective, the Commission shall notify the Department of Commerce and Economic Opportunity of any electric utility serving adversely impacted residential and small commercial customers with an approved tariff that is eligible to receive funds to be used to pay for the monthly rebate credits issued pursuant to this Section.

(e) Each electric utility providing a monthly rebate credit to its customers pursuant to subsection (c) shall include at least the following statement as part of a bill insert or bill message provided with any bill reflecting a monthly rebate credit to customers: "Your bill has been reduced this month by the Power Price Mitigation Rebate Act passed by the Illinois General Assembly." The amount of the monthly rebate credit being applied for the billing period shall also be reflected on the customer's bill with the description "State Funded Power Price Mitigation Credit". The electric utility's obligation to reflect the information required by this subsection shall not extend past the October 2023 billing period.

(f) An electric utility with a tariff approved pursuant to subsection (c) shall be entitled to recover the reasonable and prudent expenses incurred to comply with this Section and shall have an obligation to provide monthly rebate credits to customers only to the extent there are funds available to the utility to provide the monthly rebate credits, as funded by the Department of Commerce and Economic Opportunity and subject to appropriation to the Department. Within 180 days from the date on which all allocated funds have been transferred to and applied by the electric utility, the electric utility shall notify the Commission and provide an accounting for all funds applied as a monthly rebate credit to its residential and small commercial customers. The electric utility shall take reasonable steps to apply all allocated funds it receives as monthly rebate credits. If any funds remain after the October 2023 billing period that have not been applied to residential or small commercial customers, the electric utility shall return such unapplied amounts to the Department of Commerce and Economic Opportunity by March 30, 2024. If the electric utility provides rebate credits to customers that exceed the available funds, the electric utility shall account for such amounts and the utility shall recover those amounts not to exceed 2% of the total available funds made available for the rebate credits as part of its next base rates increase pursuant to Article XVI or Article IX.

(g) This Section, except for this subsection and subsection (f), is inoperative on and after January 1, 2025.

(h) This Section may be referred to as the Power Price Mitigation Rebate Act.

(Source: P.A. 102-1123, eff. 1-27-23.)

(220 ILCS 5/16-108)

Sec. 16-108. Recovery of costs associated with the provision of delivery and other services.

(a) An electric utility shall file a delivery services tariff with the Commission at least 210 days prior to the date that it is required to begin offering such services pursuant to this Act. An electric utility shall provide the components of delivery services that are subject to the jurisdiction of the Federal Energy Regulatory Commission at the same prices, terms and conditions set forth in its applicable tariff as approved or allowed into effect by that Commission. The Commission shall otherwise have the authority pursuant to Article IX to review, approve, and modify the prices, terms and conditions of those components of delivery services not subject to the jurisdiction of the Federal Energy Regulatory Commission, including the authority to determine the extent to which such delivery services should be offered on an unbundled basis. In making any such determination the Commission shall consider, at a minimum, the effect of additional unbundling on (i) the objective of just and reasonable rates, (ii) electric utility employees, and (iii) the development of competitive markets for electric energy services in Illinois.

(b) The Commission shall enter an order approving, or approving as modified, the delivery services tariff no later than 30 days prior to the date on which the electric utility must commence offering such services. The Commission may subsequently modify such tariff pursuant to this Act.

(c) The electric utility's tariffs shall define the classes of its customers for purposes of delivery services charges. Delivery services shall be priced and made available to all retail customers electing delivery services in each such class on a nondiscriminatory basis regardless of whether the retail customer chooses the electric utility, an affiliate of the electric utility, or another entity as its supplier of electric power and energy. Charges for delivery services shall be cost based, and shall allow the electric utility to recover the costs of providing delivery services through its charges to its delivery service customers that use the facilities and services associated with such costs. Such costs shall include the costs of owning, operating and maintaining transmission and distribution facilities. The Commission shall also be authorized to consider whether, and if so to what extent, the following costs are appropriately included in the electric utility's delivery services rates: (i) the costs of that portion of generation facilities used for the production and absorption of reactive power in order that retail customers located in the electric utility's service area can receive electric power and energy from suppliers other than the electric utility, and (ii) the costs associated with the use and redispatch of generation facilities to mitigate constraints on the transmission or distribution system in order that retail customers located in the electric utility's service area can receive electric power and energy from suppliers other than the electric utility. Nothing in this subsection shall be construed as directing the Commission to allocate any of the costs described in (i) or (ii) that are found to be appropriately included in the electric utility's delivery services rates to any particular customer group or geographic area in setting delivery services rates.

(d) The Commission shall establish charges, terms and conditions for delivery services that are just and reasonable and shall take into account customer impacts when establishing such charges. In establishing charges, terms and conditions for delivery services, the Commission shall take into account voltage level differences. A retail customer shall have the option to request to purchase electric service at any delivery service voltage reasonably and technically feasible from the electric facilities serving that customer's premises provided that there are no significant adverse impacts upon system reliability or system efficiency. A retail customer shall also have the option to request to purchase electric service at any point of delivery that is reasonably and technically feasible provided that there are no significant adverse impacts on system reliability or efficiency. Such requests shall not be unreasonably denied.

(e) Electric utilities shall recover the costs of installing, operating or maintaining facilities for the particular benefit of one or more delivery services customers, including without limitation any costs incurred in complying with a customer's request to be served at a different voltage level, directly from the retail customer or customers for whose benefit the costs were incurred, to the extent such costs are not recovered through the charges referred to in subsections (c) and (d) of this Section.

(f) An electric utility shall be entitled but not required to implement transition charges in conjunction with the offering of delivery services pursuant to Section 16-104. If an electric utility implements transition charges, it shall implement such charges for all delivery services customers and for all customers described in subsection (h), but shall not implement transition charges for power and energy that a retail customer takes from cogeneration or self-generation facilities located on that retail customer's premises, if such facilities meet the following criteria:

(i) the cogeneration or self-generation facilities serve a single retail customer and are located on that retail customer's premises (for purposes of this subparagraph and subparagraph (ii), an industrial or manufacturing retail customer and a third party contractor that is served by such industrial or manufacturing customer through such retail customer's own electrical distribution facilities under the circumstances described in subsection (vi) of the definition of "alternative retail electric supplier" set forth in Section 16-102, shall be considered a single retail customer);

(ii) the cogeneration or self-generation facilities either (A) are sized pursuant to generally accepted engineering standards for the retail customer's electrical load at that premises (taking into account standby or other reliability considerations related to that retail customer's operations at that site) or (B) if the facility is a cogeneration facility located on the retail customer's premises, the retail customer is the thermal host for that facility and the facility has been designed to meet that retail customer's thermal energy requirements resulting in electrical output beyond that retail customer's electrical demand at that premises, comply with the operating and efficiency standards applicable to "qualifying facilities" specified in title 18 Code of Federal Regulations Section 292.205 as in effect on the effective date of this amendatory Act of 1999;

(iii) the retail customer on whose premises the facilities are located either has an exclusive right to receive, and corresponding obligation to pay for, all of the electrical capacity of the facility, or in the case of a cogeneration facility that has been designed to meet the retail customer's thermal energy requirements at that premises, an identified amount of the electrical capacity of the facility, over a minimum 5-year period; and

(iv) if the cogeneration facility is sized for the retail customer's thermal load at that premises but exceeds the electrical load, any sales of excess power or energy are made only at wholesale, are subject to the jurisdiction of the Federal Energy Regulatory Commission, and are not for the purpose of circumventing the provisions of this subsection (f).

If a generation facility located at a retail customer's premises does not meet the above criteria, an electric utility implementing transition charges shall implement a transition charge until December 31, 2006 for any power and energy taken by such retail customer from such facility as if such power and energy had been delivered by the electric utility. Provided, however, that an industrial retail customer that is taking power from a generation facility that does not meet the above criteria but that is located on such customer's premises will not be subject to a transition charge for the power and energy taken by such retail customer from such generation facility if the facility does not serve any other retail customer and either was installed on behalf of the customer and for its own use prior to January 1, 1997, or is both predominantly fueled by byproducts of such customer's manufacturing process at such premises and sells or offers an average of 300 megawatts or more of electricity produced from such generation facility into the wholesale market. Such charges shall be calculated as provided in Section 16-102, and shall be collected on each kilowatt-hour delivered under a delivery services tariff to a retail customer from the date the customer first takes delivery services until December 31, 2006 except as provided in subsection (h) of this Section. Provided, however, that an electric utility, other than an electric utility providing service to at least 1,000,000 customers in this State on January 1, 1999, shall be entitled to petition for entry of an order by the Commission authorizing the electric utility to implement transition charges for an additional period ending no later than December 31, 2008. The electric utility shall file its petition with supporting evidence no earlier than 16 months, and no later than 12 months, prior to December 31, 2006. The Commission shall hold a hearing on the electric utility's petition and shall enter its order no later than 8 months after the petition is filed. The Commission shall determine whether and to what extent the electric utility shall be authorized to implement transition charges for an additional period. The Commission may authorize the electric utility to implement transition charges for some or all of the additional period, and shall determine the mitigation factors to be used in implementing such transition charges; provided, that the Commission shall not authorize mitigation factors less than 110% of those in effect during the 12 months ended December 31, 2006. In making its determination, the Commission shall consider the following factors: the necessity to implement transition charges for an additional period in order to maintain the financial integrity of the electric utility; the prudence of the electric utility's actions in reducing its costs since the effective date of this amendatory Act of 1997; the ability of the electric utility to provide safe, adequate and reliable service to retail customers in its service area; and the impact on competition of allowing the electric utility to implement transition charges for the additional period.

(g) The electric utility shall file tariffs that establish the transition charges to be paid by each class of customers to the electric utility in conjunction with the provision of delivery services. The electric utility's tariffs shall define the classes of its customers for purposes of calculating transition charges. The electric utility's tariffs shall provide for the calculation of transition charges on a customer-specific basis for any retail customer whose average monthly maximum electrical demand on the electric utility's system during the 6 months with the customer's highest monthly maximum electrical demands equals or exceeds 3.0 megawatts for electric utilities having more than 1,000,000 customers, and for other electric utilities for any customer that has an average monthly maximum electrical demand on the electric utility's system of one megawatt or more, and (A) for which there exists data on the customer's usage during the 3 years preceding the date that the customer became eligible to take delivery services, or (B) for which there does not exist data on the customer's usage during the 3 years preceding the date that the customer became eligible to take delivery services, if in the electric utility's reasonable judgment there exists comparable usage information or a sufficient basis to develop such information, and further provided that the electric utility can require customers for which an individual calculation is made to sign contracts that set forth the transition charges to be paid by the customer to the electric utility pursuant to the tariff.

(h) An electric utility shall also be entitled to file tariffs that allow it to collect transition charges from retail customers in the electric utility's service area that do not take delivery services but that take electric power or energy from an alternative retail electric supplier or from an electric utility other than the electric utility in whose service area the customer is located. Such charges shall be calculated, in accordance with the definition of transition charges in Section 16-102, for the period of time that the customer would be obligated to pay transition charges if it were taking delivery services, except that no deduction for delivery services revenues shall be made in such calculation, and usage data from the customer's class shall be used where historical usage data is not available for the individual customer. The customer shall be obligated to pay such charges on a lump sum basis on or before the date on which the customer commences to take service from the alternative retail electric supplier or other electric utility, provided, that the electric utility in whose service area the customer is located shall offer the customer the option of signing a contract pursuant to which the customer pays such charges ratably over the period in which the charges would otherwise have applied.

(i) An electric utility shall be entitled to add to the bills of delivery services customers charges pursuant to Sections 9-221, 9-222 (except as provided in Section 9-222.1), and Section 16-114 of this Act, Section 5-5 of the Electricity Infrastructure Maintenance Fee Law, Section 6-5 of the Renewable Energy, Energy Efficiency, and Coal Resources Development Law of 1997, and Section 13 of the Energy Assistance Act.

(i-5) An electric utility required to impose the Coal to Solar and Energy Storage Initiative Charge provided for in subsection (c-5) of Section 1-75 of the Illinois Power Agency Act shall add such charge to the bills of its delivery services customers pursuant to the terms of a tariff conforming to the requirements of subsection (c-5) of Section 1-75 of the Illinois Power Agency Act and this subsection (i-5) and filed with and approved by the Commission. The electric utility shall file its proposed tariff with the Commission on or before July 1, 2022 to be effective, after review and approval or modification by the Commission, beginning January 1, 2023. On or before December 1, 2022, the Commission shall review the electric utility's proposed tariff, including by conducting a docketed proceeding if deemed necessary by the Commission, and shall approve the proposed tariff or direct the electric utility to make modifications the Commission finds necessary for the tariff to conform to the requirements of subsection (c-5) of Section 1-75 of the Illinois Power Agency Act and this subsection (i-5). The electric utility's tariff shall provide for imposition of the Coal to Solar and Energy Storage Initiative Charge on a per-kilowatthour basis to all kilowatthours delivered by the electric utility to its delivery services customers. The tariff shall provide for the calculation of the Coal to Solar and Energy Storage Initiative Charge to be in effect for the year beginning January 1, 2023 and each year beginning January 1 thereafter, sufficient to collect the electric utility's estimated payment obligations for the delivery year beginning the following June 1 under contracts for purchase of renewable energy credits entered into pursuant to subsection (c-5) of Section 1-75 of the Illinois Power Agency Act and the obligations of the Department of Commerce and Economic Opportunity, or any successor department or agency, which for purposes of this subsection (i-5) shall be referred to as the Department, to make grant payments during such delivery year from the Coal to Solar and Energy Storage Initiative Fund pursuant to grant contracts entered into pursuant to subsection (c-5) of Section 1-75 of the Illinois Power Agency Act, and using the electric utility's kilowatthour deliveries to its delivery services customers during the delivery year ended May 31 of the preceding calendar year. On or before November 1 of each year beginning November 1, 2022, the Department shall notify the electric utilities of the amount of the Department's estimated obligations for grant payments during the delivery year beginning the following June 1 pursuant to grant contracts entered into pursuant to subsection (c-5) of Section 1-75 of the Illinois Power Agency Act; and each electric utility shall incorporate in the calculation of its Coal to Solar and Energy Storage Initiative Charge the fractional portion of the Department's estimated obligations equal to the electric utility's kilowatthour deliveries to its delivery services customers in the delivery year ended the preceding May 31 divided by the aggregate deliveries of both electric utilities to delivery services customers in such delivery year. The electric utility shall remit on a monthly basis to the State Treasurer, for deposit in the Coal to Solar and Energy Storage Initiative Fund provided for in subsection (c-5) of Section 1-75 of the Illinois Power Agency Act, the electric utility's collections of the Coal to Solar and Energy Storage Initiative Charge estimated to be needed by the Department for grant payments pursuant to grant contracts entered into pursuant to subsection (c-5) of Section 1-75 of the Illinois Power Agency Act. The initial charge under the electric utility's tariff shall be effective for kilowatthours delivered beginning January 1, 2023, and thereafter shall be revised to be effective January 1, 2024 and each January 1 thereafter, based on the payment obligations for the delivery year beginning the following June 1. The tariff shall provide for the electric utility to make an annual filing with the Commission on or before November 15 of each year, beginning in 2023, setting forth the Coal to Solar and Energy Storage Initiative Charge to be in effect for the year beginning the following January 1. The electric utility's tariff shall also provide that the electric utility shall make a filing with the Commission on or before August 1 of each year beginning in 2024 setting forth a reconciliation, for the delivery year ended the preceding May 31, of the electric utility's collections of the Coal to Solar and Energy Storage Initiative Charge against actual payments for renewable energy credits pursuant to contracts entered into, and the actual grant payments by the Department pursuant to grant contracts entered into, pursuant to subsection (c-5) of Section 1-75 of the Illinois Power Agency Act. The tariff shall provide that any excess or shortfall of collections to payments shall be deducted from or added to, on a per-kilowatthour basis, the Coal to Solar and Energy Storage Initiative Charge, over the 6-month period beginning October 1 of that calendar year.

(j) If a retail customer that obtains electric power and energy from cogeneration or self-generation facilities installed for its own use on or before January 1, 1997, subsequently takes service from an alternative retail electric supplier or an electric utility other than the electric utility in whose service area the customer is located for any portion of the customer's electric power and energy requirements formerly obtained from those facilities (including that amount purchased from the utility in lieu of such generation and not as standby power purchases, under a cogeneration displacement tariff in effect as of the effective date of this amendatory Act of 1997), the transition charges otherwise applicable pursuant to subsections (f), (g), or (h) of this Section shall not be applicable in any year to that portion of the customer's electric power and energy requirements formerly obtained from those facilities, provided, that for purposes of this subsection (j), such portion shall not exceed the average number of kilowatt-hours per year obtained from the cogeneration or self-generation facilities during the 3 years prior to the date on which the customer became eligible for delivery services, except as provided in subsection (f) of Section 16-110.

(k) The electric utility shall be entitled to recover through tariffed charges all of the costs associated with the purchase of zero emission credits from zero emission facilities to meet the requirements of subsection (d-5) of Section 1-75 of the Illinois Power Agency Act and all of the costs associated with the purchase of carbon mitigation credits from carbon-free energy resources to meet the requirements of subsection (d-10) of Section 1-75 of the Illinois Power Agency Act. Such costs shall include the costs of procuring the zero emission credits and carbon mitigation credits from carbon-free energy resources, as well as the reasonable costs that the utility incurs as part of the procurement processes and to implement and comply with plans and processes approved by the Commission under subsections (d-5) and (d-10). The costs shall be allocated across all retail customers through a single, uniform cents per kilowatt-hour charge applicable to all retail customers, which shall appear as a separate line item on each customer's bill. Beginning June 1, 2017, the electric utility shall be entitled to recover through tariffed charges all of the costs associated with the purchase of renewable energy resources to meet the renewable energy resource standards of subsection (c) of Section 1-75 of the Illinois Power Agency Act, under procurement plans as approved in accordance with that Section and Section 16-111.5 of this Act. Such costs shall include the costs of procuring the renewable energy resources, as well as the reasonable costs that the utility incurs as part of the procurement processes and to implement and comply with plans and processes approved by the Commission under such Sections. The costs associated with the purchase of renewable energy resources shall be allocated across all retail customers in proportion to the amount of renewable energy resources the utility procures for such customers through a single, uniform cents per kilowatt-hour charge applicable to such retail customers, which shall appear as a separate line item on each such customer's bill. The credits, costs, and penalties associated with the self-direct renewable portfolio standard compliance program described in subparagraph (R) of paragraph (1) of subsection (c) of Section 1-75 of the Illinois Power Agency Act shall be allocated to approved eligible self-direct customers by the utility in a cents per kilowatt-hour credit, cost, or penalty, which shall appear as a separate line item on each such customer's bill.

Notwithstanding whether the Commission has approved the initial long-term renewable resources procurement plan as of June 1, 2017, an electric utility shall place new tariffed charges into effect beginning with the June 2017 monthly billing period, to the extent practicable, to begin recovering the costs of procuring renewable energy resources, as those charges are calculated under the limitations described in subparagraph (E) of paragraph (1) of subsection (c) of Section 1-75 of the Illinois Power Agency Act. Notwithstanding the date on which the utility places such new tariffed charges into effect, the utility shall be permitted to collect the charges under such tariff as if the tariff had been in effect beginning with the first day of the June 2017 monthly billing period. For the delivery years commencing June 1, 2017, June 1, 2018, June 1, 2019, and each delivery year thereafter, the electric utility shall deposit into a separate interest bearing account of a financial institution the monies collected under the tariffed charges. Money collected from customers for the procurement of renewable energy resources in a given delivery year may be spent by the utility for the procurement of renewable resources over any of the following 5 delivery years, after which unspent money shall be credited back to retail customers. The electric utility shall spend all money collected in earlier delivery years that has not yet been returned to customers, first, before spending money collected in later delivery years. Any interest earned shall be credited back to retail customers under the reconciliation proceeding provided for in this subsection (k), provided that the electric utility shall first be reimbursed from the interest for the administrative costs that it incurs to administer and manage the account. Any taxes due on the funds in the account, or interest earned on it, will be paid from the account or, if insufficient monies are available in the account, from the monies collected under the tariffed charges to recover the costs of procuring renewable energy resources. Monies deposited in the account shall be subject to the review, reconciliation, and true-up process described in this subsection (k) that is applicable to the funds collected and costs incurred for the procurement of renewable energy resources.

The electric utility shall be entitled to recover all of the costs identified in this subsection (k) through automatic adjustment clause tariffs applicable to all of the utility's retail customers that allow the electric utility to adjust its tariffed charges consistent with this subsection (k). The determination as to whether any excess funds were collected during a given delivery year for the purchase of renewable energy resources, and the crediting of any excess funds back to retail customers, shall not be made until after the close of the delivery year, which will ensure that the maximum amount of funds is available to implement the approved long-term renewable resources procurement plan during a given delivery year. The amount of excess funds eligible to be credited back to retail customers shall be reduced by an amount equal to the payment obligations required by any contracts entered into by an electric utility under contracts described in subsection (b) of Section 1-56 and subsection (c) of Section 1-75 of the Illinois Power Agency Act, even if such payments have not yet been made and regardless of the delivery year in which those payment obligations were incurred. Notwithstanding anything to the contrary, including in tariffs authorized by this subsection (k) in effect before the effective date of this amendatory Act of the 102nd General Assembly, all unspent funds as of May 31, 2021, excluding any funds credited to customers during any utility billing cycle that commences prior to the effective date of this amendatory Act of the 102nd General Assembly, shall remain in the utility account and shall on a first in, first out basis be used toward utility payment obligations under contracts described in subsection (b) of Section 1-56 and subsection (c) of Section 1-75 of the Illinois Power Agency Act. The electric utility's collections under such automatic adjustment clause tariffs to recover the costs of renewable energy resources, zero emission credits from zero emission facilities, and carbon mitigation credits from carbon-free energy resources shall be subject to separate annual review, reconciliation, and true-up against actual costs by the Commission under a procedure that shall be specified in the electric utility's automatic adjustment clause tariffs and that shall be approved by the Commission in connection with its approval of such tariffs. The procedure shall provide that any difference between the electric utility's collections for zero emission credits and carbon mitigation credits under the automatic adjustment charges for an annual period and the electric utility's actual costs of zero emission credits from zero emission facilities and carbon mitigation credits from carbon-free energy resources for that same annual period shall be refunded to or collected from, as applicable, the electric utility's retail customers in subsequent periods.

Nothing in this subsection (k) is intended to affect, limit, or change the right of the electric utility to recover the costs associated with the procurement of renewable energy resources for periods commencing before, on, or after June 1, 2017, as otherwise provided in the Illinois Power Agency Act.

The funding available under this subsection (k), if any, for the programs described under subsection (b) of Section 1-56 of the Illinois Power Agency Act shall not reduce the amount of funding for the programs described in subparagraph (O) of paragraph (1) of subsection (c) of Section 1-75 of the Illinois Power Agency Act. If funding is available under this subsection (k) for programs described under subsection (b) of Section 1-56 of the Illinois Power Agency Act, then the long-term renewable resources plan shall provide for the Agency to procure contracts in an amount that does not exceed the funding, and the contracts approved by the Commission shall be executed by the applicable utility or utilities.

(l) A utility that has terminated any contract executed under subsection (d-5) or (d-10) of Section 1-75 of the Illinois Power Agency Act shall be entitled to recover any remaining balance associated with the purchase of zero emission credits prior to such termination, and such utility shall also apply a credit to its retail customer bills in the event of any over-collection.

(m)(1) An electric utility that recovers its costs of procuring zero emission credits from zero emission facilities through a cents-per-kilowatthour charge under subsection (k) of this Section shall be subject to the requirements of this subsection (m). Notwithstanding anything to the contrary, such electric utility shall, beginning on April 30, 2018, and each April 30 thereafter until April 30, 2026, calculate whether any reduction must be applied to such cents-per-kilowatthour charge that is paid by retail customers of the electric utility that have opted out of subsections (a) through (j) of Section 8-103B of this Act under subsection (l) of Section 8-103B. Such charge shall be reduced for such customers for the next delivery year commencing on June 1 based on the amount necessary, if any, to limit the annual estimated average net increase for the prior calendar year due to the future energy investment costs to no more than 1.3% of 5.98 cents per kilowatt-hour, which is the average amount paid per kilowatthour for electric service during the year ending December 31, 2015 by Illinois industrial retail customers, as reported to the Edison Electric Institute.

The calculations required by this subsection (m) shall be made only once for each year, and no subsequent rate impact determinations shall be made.

(2) For purposes of this Section, "future energy investment costs" shall be calculated by subtracting the cents-per-kilowatthour charge identified in subparagraph (A) of this paragraph (2) from the sum of the cents-per-kilowatthour charges identified in subparagraph (B) of this paragraph (2):

(A) The cents-per-kilowatthour charge identified in the electric utility's tariff placed into effect under Section 8-103 of the Public Utilities Act that, on December 1, 2016, was applicable to those retail customers that have opted out of subsections (a) through (j) of Section 8-103B of this Act under subsection (l) of Section 8-103B.

(B) The sum of the following cents-per-kilowatthour charges applicable to those retail customers that have opted out of subsections (a) through (j) of Section 8-103B of this Act under subsection (l) of Section 8-103B, provided that if one or more of the following charges has been in effect and applied to such customers for more than one calendar year, then each charge shall be equal to the average of the charges applied over a period that commences with the calendar year ending December 31, 2017 and ends with the most recently completed calendar year prior to the calculation required by this subsection (m):

(i) the cents-per-kilowatthour charge to recover the costs incurred by the utility under subsection (d-5) of Section 1-75 of the Illinois Power Agency Act, adjusted for any reductions required under this subsection (m); and

(ii) the cents-per-kilowatthour charge to recover the costs incurred by the utility under Section 16-107.6 of the Public Utilities Act.

If no charge was applied for a given calendar year under item (i) or (ii) of this subparagraph (B), then the value of the charge for that year shall be zero.

(3) If a reduction is required by the calculation performed under this subsection (m), then the amount of the reduction shall be multiplied by the number of years reflected in the averages calculated under subparagraph (B) of paragraph (2) of this subsection (m). Such reduction shall be applied to the cents-per-kilowatthour charge that is applicable to those retail customers that have opted out of subsections (a) through (j) of Section 8-103B of this Act under subsection (l) of Section 8-103B beginning with the next delivery year commencing after the date of the calculation required by this subsection (m).

(4) The electric utility shall file a notice with the Commission on May 1 of 2018 and each May 1 thereafter until May 1, 2026 containing the reduction, if any, which must be applied for the delivery year which begins in the year of the filing. The notice shall contain the calculations made pursuant to this Section. By October 1 of each year beginning in 2018, each electric utility shall notify the Commission if it appears, based on an estimate of the calculation required in this subsection (m), that a reduction will be required in the next year.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-108.5)

Sec. 16-108.5. Infrastructure investment and modernization; regulatory reform.

(a) (Blank).

(b) For purposes of this Section, "participating utility" means an electric utility or a combination utility serving more than 1,000,000 customers in Illinois that voluntarily elects and commits to undertake (i) the infrastructure investment program consisting of the commitments and obligations described in this subsection (b) and (ii) the customer assistance program consisting of the commitments and obligations described in subsection (b-10) of this Section, notwithstanding any other provisions of this Act and without obtaining any approvals from the Commission or any other agency other than as set forth in this Section, regardless of whether any such approval would otherwise be required. "Combination utility" means a utility that, as of January 1, 2011, provided electric service to at least one million retail customers in Illinois and gas service to at least 500,000 retail customers in Illinois. A participating utility shall recover the expenditures made under the infrastructure investment program through the ratemaking process, including, but not limited to, the performance-based formula rate and process set forth in this Section.

During the infrastructure investment program's peak program year, a participating utility other than a combination utility shall create 2,000 full-time equivalent jobs in Illinois, and a participating utility that is a combination utility shall create 450 full-time equivalent jobs in Illinois related to the provision of electric service. These jobs shall include direct jobs, contractor positions, and induced jobs, but shall not include any portion of a job commitment, not specifically contingent on an amendatory Act of the 97th General Assembly becoming law, between a participating utility and a labor union that existed on December 30, 2011 (the effective date of Public Act 97-646) and that has not yet been fulfilled. A portion of the full-time equivalent jobs created by each participating utility shall include incremental personnel hired subsequent to December 30, 2011 (the effective date of Public Act 97-646). For purposes of this Section, "peak program year" means the consecutive 12-month period with the highest number of full-time equivalent jobs that occurs between the beginning of investment year 2 and the end of investment year 4.

A participating utility shall meet one of the following commitments, as applicable:

(1) Beginning no later than 180 days after a participating utility other than a combination utility files a performance-based formula rate tariff pursuant to subsection (c) of this Section, or, beginning no later than January 1, 2012 if such utility files such performance-based formula rate tariff within 14 days of October 26, 2011 (the effective date of Public Act 97-616), the participating utility shall, except as provided in subsection (b-5):

(A) over a 5-year period, invest an estimated $1,300,000,000 in electric system upgrades, modernization projects, and training facilities, including, but not limited to:

(i) distribution infrastructure improvements totaling an estimated $1,000,000,000, including underground residential distribution cable injection and replacement and mainline cable system refurbishment and replacement projects;

(ii) training facility construction or upgrade projects totaling an estimated $10,000,000, provided that, at a minimum, one such facility shall be located in a municipality having a population of more than 2 million residents and one such facility shall be located in a municipality having a population of more than 150,000 residents but fewer than 170,000 residents; any such new facility located in a municipality having a population of more than 2 million residents must be designed for the purpose of obtaining, and the owner of the facility shall apply for, certification under the United States Green Building Council's Leadership in Energy Efficiency Design Green Building Rating System;

(iii) wood pole inspection, treatment, and replacement programs;

(iv) an estimated $200,000,000 for reducing the susceptibility of certain circuits to storm-related damage, including, but not limited to, high winds, thunderstorms, and ice storms; improvements may include, but are not limited to, overhead to underground conversion and other engineered outcomes for circuits; the participating utility shall prioritize the selection of circuits based on each circuit's historical susceptibility to storm-related damage and the ability to provide the greatest customer benefit upon completion of the improvements; to be eligible for improvement, the participating utility's ability to maintain proper tree clearances surrounding the overhead circuit must not have been impeded by third parties; and

(B) over a 10-year period, invest an estimated $1,300,000,000 to upgrade and modernize its transmission and distribution infrastructure and in Smart Grid electric system upgrades, including, but not limited to:

(i) additional smart meters;

(ii) distribution automation;

(iii) associated cyber secure data communication network; and

(iv) substation micro-processor relay upgrades.

(2) Beginning no later than 180 days after a participating utility that is a combination utility files a performance-based formula rate tariff pursuant to subsection (c) of this Section, or, beginning no later than January 1, 2012 if such utility files such performance-based formula rate tariff within 14 days of October 26, 2011 (the effective date of Public Act 97-616), the participating utility shall, except as provided in subsection (b-5):

(A) over a 10-year period, invest an estimated $265,000,000 in electric system upgrades, modernization projects, and training facilities, including, but not limited to:

(i) distribution infrastructure improvements totaling an estimated $245,000,000, which may include bulk supply substations, transformers, reconductoring, and rebuilding overhead distribution and sub-transmission lines, underground residential distribution cable injection and replacement and mainline cable system refurbishment and replacement projects;

(ii) training facility construction or upgrade projects totaling an estimated $1,000,000; any such new facility must be designed for the purpose of obtaining, and the owner of the facility shall apply for, certification under the United States Green Building Council's Leadership in Energy Efficiency Design Green Building Rating System; and

(iii) wood pole inspection, treatment, and replacement programs; and

(B) over a 10-year period, invest an estimated $360,000,000 to upgrade and modernize its transmission and distribution infrastructure and in Smart Grid electric system upgrades, including, but not limited to:

(i) additional smart meters;

(ii) distribution automation;

(iii) associated cyber secure data communication network; and

(iv) substation micro-processor relay upgrades.

For purposes of this Section, "Smart Grid electric system upgrades" shall have the meaning set forth in subsection (a) of Section 16-108.6 of this Act.

The investments in the infrastructure investment program described in this subsection (b) shall be incremental to the participating utility's annual capital investment program, as defined by, for purposes of this subsection (b), the participating utility's average capital spend for calendar years 2008, 2009, and 2010 as reported in the applicable Federal Energy Regulatory Commission (FERC) Form 1; provided that where one or more utilities have merged, the average capital spend shall be determined using the aggregate of the merged utilities' capital spend reported in FERC Form 1 for the years 2008, 2009, and 2010. A participating utility may add reasonable construction ramp-up and ramp-down time to the investment periods specified in this subsection (b). For each such investment period, the ramp-up and ramp-down time shall not exceed a total of 6 months.

Within 60 days after filing a tariff under subsection (c) of this Section, a participating utility shall submit to the Commission its plan, including scope, schedule, and staffing, for satisfying its infrastructure investment program commitments pursuant to this subsection (b). The submitted plan shall include a schedule and staffing plan for the next calendar year. The plan shall also include a plan for the creation, operation, and administration of a Smart Grid test bed as described in subsection (c) of Section 16-108.8. The plan need not allocate the work equally over the respective periods, but should allocate material increments throughout such periods commensurate with the work to be undertaken. No later than April 1 of each subsequent year, the utility shall submit to the Commission a report that includes any updates to the plan, a schedule for the next calendar year, the expenditures made for the prior calendar year and cumulatively, and the number of full-time equivalent jobs created for the prior calendar year and cumulatively. If the utility is materially deficient in satisfying a schedule or staffing plan, then the report must also include a corrective action plan to address the deficiency. The fact that the plan, implementation of the plan, or a schedule changes shall not imply the imprudence or unreasonableness of the infrastructure investment program, plan, or schedule. Further, no later than 45 days following the last day of the first, second, and third quarters of each year of the plan, a participating utility shall submit to the Commission a verified quarterly report for the prior quarter that includes (i) the total number of full-time equivalent jobs created during the prior quarter, (ii) the total number of employees as of the last day of the prior quarter, (iii) the total number of full-time equivalent hours in each job classification or job title, (iv) the total number of incremental employees and contractors in support of the investments undertaken pursuant to this subsection (b) for the prior quarter, and (v) any other information that the Commission may require by rule.

With respect to the participating utility's peak job commitment, if, after considering the utility's corrective action plan and compliance thereunder, the Commission enters an order finding, after notice and hearing, that a participating utility did not satisfy its peak job commitment described in this subsection (b) for reasons that are reasonably within its control, then the Commission shall also determine, after consideration of the evidence, including, but not limited to, evidence submitted by the Department of Commerce and Economic Opportunity and the utility, the deficiency in the number of full-time equivalent jobs during the peak program year due to such failure. The Commission shall notify the Department of any proceeding that is initiated pursuant to this paragraph. For each full-time equivalent job deficiency during the peak program year that the Commission finds as set forth in this paragraph, the participating utility shall, within 30 days after the entry of the Commission's order, pay $6,000 to a fund for training grants administered under Section 605-800 of the Department of Commerce and Economic Opportunity Law, which shall not be a recoverable expense.

With respect to the participating utility's investment amount commitments, if, after considering the utility's corrective action plan and compliance thereunder, the Commission enters an order finding, after notice and hearing, that a participating utility is not satisfying its investment amount commitments described in this subsection (b), then the utility shall no longer be eligible to annually update the performance-based formula rate tariff pursuant to subsection (d) of this Section. In such event, the then current rates shall remain in effect until such time as new rates are set pursuant to Article IX of this Act, subject to retroactive adjustment, with interest, to reconcile rates charged with actual costs.

If the Commission finds that a participating utility is no longer eligible to update the performance-based formula rate tariff pursuant to subsection (d) of this Section, or the performance-based formula rate is otherwise terminated, then the participating utility's voluntary commitments and obligations under this subsection (b) shall immediately terminate, except for the utility's obligation to pay an amount already owed to the fund for training grants pursuant to a Commission order.

In meeting the obligations of this subsection (b), to the extent feasible and consistent with State and federal law, the investments under the infrastructure investment program should provide employment opportunities for all segments of the population and workforce, including minority-owned and female-owned business enterprises, and shall not, consistent with State and federal law, discriminate based on race or socioeconomic status.

(b-5) Nothing in this Section shall prohibit the Commission from investigating the prudence and reasonableness of the expenditures made under the infrastructure investment program during the annual review required by subsection (d) of this Section and shall, as part of such investigation, determine whether the utility's actual costs under the program are prudent and reasonable. The fact that a participating utility invests more than the minimum amounts specified in subsection (b) of this Section or its plan shall not imply imprudence or unreasonableness.

If the participating utility finds that it is implementing its plan for satisfying the infrastructure investment program commitments described in subsection (b) of this Section at a cost below the estimated amounts specified in subsection (b) of this Section, then the utility may file a petition with the Commission requesting that it be permitted to satisfy its commitments by spending less than the estimated amounts specified in subsection (b) of this Section. The Commission shall, after notice and hearing, enter its order approving, or approving as modified, or denying each such petition within 150 days after the filing of the petition.

In no event, absent General Assembly approval, shall the capital investment costs incurred by a participating utility other than a combination utility in satisfying its infrastructure investment program commitments described in subsection (b) of this Section exceed $3,000,000,000 or, for a participating utility that is a combination utility, $720,000,000. If the participating utility's updated cost estimates for satisfying its infrastructure investment program commitments described in subsection (b) of this Section exceed the limitation imposed by this subsection (b-5), then it shall submit a report to the Commission that identifies the increased costs and explains the reason or reasons for the increased costs no later than the year in which the utility estimates it will exceed the limitation. The Commission shall review the report and shall, within 90 days after the participating utility files the report, report to the General Assembly its findings regarding the participating utility's report. If the General Assembly does not amend the limitation imposed by this subsection (b-5), then the utility may modify its plan so as not to exceed the limitation imposed by this subsection (b-5) and may propose corresponding changes to the metrics established pursuant to subparagraphs (5) through (8) of subsection (f) of this Section, and the Commission may modify the metrics and incremental savings goals established pursuant to subsection (f) of this Section accordingly.

(b-10) All participating utilities shall make contributions for an energy low-income and support program in accordance with this subsection. Beginning no later than 180 days after a participating utility files a performance-based formula rate tariff pursuant to subsection (c) of this Section, or beginning no later than January 1, 2012 if such utility files such performance-based formula rate tariff within 14 days of December 30, 2011 (the effective date of Public Act 97-646), and without obtaining any approvals from the Commission or any other agency other than as set forth in this Section, regardless of whether any such approval would otherwise be required, a participating utility other than a combination utility shall pay $10,000,000 per year for 5 years and a participating utility that is a combination utility shall pay $1,000,000 per year for 10 years to the energy low-income and support program, which is intended to fund customer assistance programs with the primary purpose being avoidance of imminent disconnection. Such programs may include:

(1) a residential hardship program that may partner with community-based organizations, including senior citizen organizations, and provides grants to low-income residential customers, including low-income senior citizens, who demonstrate a hardship;

(2) a program that provides grants and other bill payment concessions to veterans with disabilities who demonstrate a hardship and members of the armed services or reserve forces of the United States or members of the Illinois National Guard who are on active duty pursuant to an executive order of the President of the United States, an act of the Congress of the United States, or an order of the Governor and who demonstrate a hardship;

(3) a budget assistance program that provides tools and education to low-income senior citizens to assist them with obtaining information regarding energy usage and effective means of managing energy costs;

(4) a non-residential special hardship program that provides grants to non-residential customers such as small businesses and non-profit organizations that demonstrate a hardship, including those providing services to senior citizen and low-income customers; and

(5) a performance-based assistance program that provides grants to encourage residential customers to make on-time payments by matching a portion of the customer's payments or providing credits towards arrearages.

The payments made by a participating utility pursuant to this subsection (b-10) shall not be a recoverable expense. A participating utility may elect to fund either new or existing customer assistance programs, including, but not limited to, those that are administered by the utility.

Programs that use funds that are provided by a participating utility to reduce utility bills may be implemented through tariffs that are filed with and reviewed by the Commission. If a utility elects to file tariffs with the Commission to implement all or a portion of the programs, those tariffs shall, regardless of the date actually filed, be deemed accepted and approved, and shall become effective on December 30, 2011 (the effective date of Public Act 97-646). The participating utilities whose customers benefit from the funds that are disbursed as contemplated in this Section shall file annual reports documenting the disbursement of those funds with the Commission. The Commission has the authority to audit disbursement of the funds to ensure they were disbursed consistently with this Section.

If the Commission finds that a participating utility is no longer eligible to update the performance-based formula rate tariff pursuant to subsection (d) of this Section, or the performance-based formula rate is otherwise terminated, then the participating utility's voluntary commitments and obligations under this subsection (b-10) shall immediately terminate.

(c) A participating utility may elect to recover its delivery services costs through a performance-based formula rate approved by the Commission, which shall specify the cost components that form the basis of the rate charged to customers with sufficient specificity to operate in a standardized manner and be updated annually with transparent information that reflects the utility's actual costs to be recovered during the applicable rate year, which is the period beginning with the first billing day of January and extending through the last billing day of the following December. In the event the utility recovers a portion of its costs through automatic adjustment clause tariffs on October 26, 2011 (the effective date of Public Act 97-616), the utility may elect to continue to recover these costs through such tariffs, but then these costs shall not be recovered through the performance-based formula rate. In the event the participating utility, prior to December 30, 2011 (the effective date of Public Act 97-646), filed electric delivery services tariffs with the Commission pursuant to Section 9-201 of this Act that are related to the recovery of its electric delivery services costs that are still pending on December 30, 2011 (the effective date of Public Act 97-646), the participating utility shall, at the time it files its performance-based formula rate tariff with the Commission, also file a notice of withdrawal with the Commission to withdraw the electric delivery services tariffs previously filed pursuant to Section 9-201 of this Act. Upon receipt of such notice, the Commission shall dismiss with prejudice any docket that had been initiated to investigate the electric delivery services tariffs filed pursuant to Section 9-201 of this Act, and such tariffs and the record related thereto shall not be the subject of any further hearing, investigation, or proceeding of any kind related to rates for electric delivery services.

The performance-based formula rate shall be implemented through a tariff filed with the Commission consistent with the provisions of this subsection (c) that shall be applicable to all delivery services customers. The Commission shall initiate and conduct an investigation of the tariff in a manner consistent with the provisions of this subsection (c) and the provisions of Article IX of this Act to the extent they do not conflict with this subsection (c). Except in the case where the Commission finds, after notice and hearing, that a participating utility is not satisfying its investment amount commitments under subsection (b) of this Section, the performance-based formula rate shall remain in effect at the discretion of the utility. The performance-based formula rate approved by the Commission shall do the following:

(1) Provide for the recovery of the utility's actual costs of delivery services that are prudently incurred and reasonable in amount consistent with Commission practice and law. The sole fact that a cost differs from that incurred in a prior calendar year or that an investment is different from that made in a prior calendar year shall not imply the imprudence or unreasonableness of that cost or investment.

(2) Reflect the utility's actual year-end capital structure for the applicable calendar year, excluding goodwill, subject to a determination of prudence and reasonableness consistent with Commission practice and law. To enable the financing of the incremental capital expenditures, including regulatory assets, for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State, a participating electric utility's actual year-end capital structure that includes a common equity ratio, excluding goodwill, of up to and including 50% of the total capital structure shall be deemed reasonable and used to set rates.

(3) Include a cost of equity, which shall be calculated as the sum of the following:

(A) the average for the applicable calendar year of the monthly average yields of 30-year U.S. Treasury bonds published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication; and

(B) 580 basis points.

At such time as the Board of Governors of the Federal Reserve System ceases to include the monthly average yields of 30-year U.S. Treasury bonds in its weekly H.15 Statistical Release or successor publication, the monthly average yields of the U.S. Treasury bonds then having the longest duration published by the Board of Governors in its weekly H.15 Statistical Release or successor publication shall instead be used for purposes of this paragraph (3).

(4) Permit and set forth protocols, subject to a determination of prudence and reasonableness consistent with Commission practice and law, for the following:

(A) recovery of incentive compensation expense that is based on the achievement of operational metrics, including metrics related to budget controls, outage duration and frequency, safety, customer service, efficiency and productivity, and environmental compliance. Incentive compensation expense that is based on net income or an affiliate's earnings per share shall not be recoverable under the performance-based formula rate;

(B) recovery of pension and other post-employment benefits expense, provided that such costs are supported by an actuarial study;

(C) recovery of severance costs, provided that if the amount is over $3,700,000 for a participating utility that is a combination utility or $10,000,000 for a participating utility that serves more than 3 million retail customers, then the full amount shall be amortized consistent with subparagraph (F) of this paragraph (4);

(D) investment return at a rate equal to the utility's weighted average cost of long-term debt, on the pension assets as, and in the amount, reported in Account 186 (or in such other Account or Accounts as such asset may subsequently be recorded) of the utility's most recently filed FERC Form 1, net of deferred tax benefits;

(E) recovery of the expenses related to the Commission proceeding under this subsection (c) to approve this performance-based formula rate and initial rates or to subsequent proceedings related to the formula, provided that the recovery shall be amortized over a 3-year period; recovery of expenses related to the annual Commission proceedings under subsection (d) of this Section to review the inputs to the performance-based formula rate shall be expensed and recovered through the performance-based formula rate;

(F) amortization over a 5-year period of the full amount of each charge or credit that exceeds $3,700,000 for a participating utility that is a combination utility or $10,000,000 for a participating utility that serves more than 3 million retail customers in the applicable calendar year and that relates to a workforce reduction program's severance costs, changes in accounting rules, changes in law, compliance with any Commission-initiated audit, or a single storm or other similar expense, provided that any unamortized balance shall be reflected in the rate base. For purposes of this subparagraph (F), changes in law includes any enactment, repeal, or amendment in a law, ordinance, rule, regulation, interpretation, permit, license, consent, or order, including those relating to taxes, accounting, or to environmental matters, or in the interpretation or application thereof by any governmental authority occurring after October 26, 2011 (the effective date of Public Act 97-616);

(G) recovery of existing regulatory assets over the periods previously authorized by the Commission;

(H) historical weather normalized billing determinants; and

(I) allocation methods for common costs.

(5) Provide that if the participating utility's earned rate of return on common equity related to the provision of delivery services for the prior rate year (calculated using costs and capital structure approved by the Commission as provided in subparagraph (2) of this subsection (c), consistent with this Section, in accordance with Commission rules and orders, including, but not limited to, adjustments for goodwill, and after any Commission-ordered disallowances and taxes) is more than 50 basis points higher than the rate of return on common equity calculated pursuant to paragraph (3) of this subsection (c) (after adjusting for any penalties to the rate of return on common equity applied pursuant to the performance metrics provision of subsection (f) of this Section), then the participating utility shall apply a credit through the performance-based formula rate that reflects an amount equal to the value of that portion of the earned rate of return on common equity that is more than 50 basis points higher than the rate of return on common equity calculated pursuant to paragraph (3) of this subsection (c) (after adjusting for any penalties to the rate of return on common equity applied pursuant to the performance metrics provision of subsection (f) of this Section) for the prior rate year, adjusted for taxes. If the participating utility's earned rate of return on common equity related to the provision of delivery services for the prior rate year (calculated using costs and capital structure approved by the Commission as provided in subparagraph (2) of this subsection (c), consistent with this Section, in accordance with Commission rules and orders, including, but not limited to, adjustments for goodwill, and after any Commission-ordered disallowances and taxes) is more than 50 basis points less than the return on common equity calculated pursuant to paragraph (3) of this subsection (c) (after adjusting for any penalties to the rate of return on common equity applied pursuant to the performance metrics provision of subsection (f) of this Section), then the participating utility shall apply a charge through the performance-based formula rate that reflects an amount equal to the value of that portion of the earned rate of return on common equity that is more than 50 basis points less than the rate of return on common equity calculated pursuant to paragraph (3) of this subsection (c) (after adjusting for any penalties to the rate of return on common equity applied pursuant to the performance metrics provision of subsection (f) of this Section) for the prior rate year, adjusted for taxes.

(6) Provide for an annual reconciliation, as described in subsection (d) of this Section, with interest, of the revenue requirement reflected in rates for each calendar year, beginning with the calendar year in which the utility files its performance-based formula rate tariff pursuant to subsection (c) of this Section, with what the revenue requirement would have been had the actual cost information for the applicable calendar year been available at the filing date.

The utility shall file, together with its tariff, final data based on its most recently filed FERC Form 1, plus projected plant additions and correspondingly updated depreciation reserve and expense for the calendar year in which the tariff and data are filed, that shall populate the performance-based formula rate and set the initial delivery services rates under the formula. For purposes of this Section, "FERC Form 1" means the Annual Report of Major Electric Utilities, Licensees and Others that electric utilities are required to file with the Federal Energy Regulatory Commission under the Federal Power Act, Sections 3, 4(a), 304 and 209, modified as necessary to be consistent with 83 Ill. Adm. Code Part 415 as of May 1, 2011. Nothing in this Section is intended to allow costs that are not otherwise recoverable to be recoverable by virtue of inclusion in FERC Form 1.

After the utility files its proposed performance-based formula rate structure and protocols and initial rates, the Commission shall initiate a docket to review the filing. The Commission shall enter an order approving, or approving as modified, the performance-based formula rate, including the initial rates, as just and reasonable within 270 days after the date on which the tariff was filed, or, if the tariff is filed within 14 days after October 26, 2011 (the effective date of Public Act 97-616), then by May 31, 2012. Such review shall be based on the same evidentiary standards, including, but not limited to, those concerning the prudence and reasonableness of the costs incurred by the utility, the Commission applies in a hearing to review a filing for a general increase in rates under Article IX of this Act. The initial rates shall take effect within 30 days after the Commission's order approving the performance-based formula rate tariff.

Until such time as the Commission approves a different rate design and cost allocation pursuant to subsection (e) of this Section, rate design and cost allocation across customer classes shall be consistent with the Commission's most recent order regarding the participating utility's request for a general increase in its delivery services rates.

Subsequent changes to the performance-based formula rate structure or protocols shall be made as set forth in Section 9-201 of this Act, but nothing in this subsection (c) is intended to limit the Commission's authority under Article IX and other provisions of this Act to initiate an investigation of a participating utility's performance-based formula rate tariff, provided that any such changes shall be consistent with paragraphs (1) through (6) of this subsection (c). Any change ordered by the Commission shall be made at the same time new rates take effect following the Commission's next order pursuant to subsection (d) of this Section, provided that the new rates take effect no less than 30 days after the date on which the Commission issues an order adopting the change.

A participating utility that files a tariff pursuant to this subsection (c) must submit a one-time $200,000 filing fee at the time the Chief Clerk of the Commission accepts the filing, which shall be a recoverable expense.

In the event the performance-based formula rate is terminated, the then current rates shall remain in effect until such time as new rates are set pursuant to Article IX of this Act, subject to retroactive rate adjustment, with interest, to reconcile rates charged with actual costs. At such time that the performance-based formula rate is terminated, the participating utility's voluntary commitments and obligations under subsection (b) of this Section shall immediately terminate, except for the utility's obligation to pay an amount already owed to the fund for training grants pursuant to a Commission order issued under subsection (b) of this Section.

(d) Subsequent to the Commission's issuance of an order approving the utility's performance-based formula rate structure and protocols, and initial rates under subsection (c) of this Section, the utility shall file, on or before May 1 of each year, with the Chief Clerk of the Commission its updated cost inputs to the performance-based formula rate for the applicable rate year and the corresponding new charges. Each such filing shall conform to the following requirements and include the following information:

(1) The inputs to the performance-based formula rate for the applicable rate year shall be based on final historical data reflected in the utility's most recently filed annual FERC Form 1 plus projected plant additions and correspondingly updated depreciation reserve and expense for the calendar year in which the inputs are filed. The filing shall also include a reconciliation of the revenue requirement that was in effect for the prior rate year (as set by the cost inputs for the prior rate year) with the actual revenue requirement for the prior rate year (determined using a year-end rate base) that uses amounts reflected in the applicable FERC Form 1 that reports the actual costs for the prior rate year. Any over-collection or under-collection indicated by such reconciliation shall be reflected as a credit against, or recovered as an additional charge to, respectively, with interest calculated at a rate equal to the utility's weighted average cost of capital approved by the Commission for the prior rate year, the charges for the applicable rate year. Provided, however, that the first such reconciliation shall be for the calendar year in which the utility files its performance-based formula rate tariff pursuant to subsection (c) of this Section and shall reconcile (i) the revenue requirement or requirements established by the rate order or orders in effect from time to time during such calendar year (weighted, as applicable) with (ii) the revenue requirement determined using a year-end rate base for that calendar year calculated pursuant to the performance-based formula rate using (A) actual costs for that year as reflected in the applicable FERC Form 1, and (B) for the first such reconciliation only, the cost of equity, which shall be calculated as the sum of 590 basis points plus the average for the applicable calendar year of the monthly average yields of 30-year U.S. Treasury bonds published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication. The first such reconciliation is not intended to provide for the recovery of costs previously excluded from rates based on a prior Commission order finding of imprudence or unreasonableness. Each reconciliation shall be certified by the participating utility in the same manner that FERC Form 1 is certified. The filing shall also include the charge or credit, if any, resulting from the calculation required by paragraph (6) of subsection (c) of this Section.

Notwithstanding anything that may be to the contrary, the intent of the reconciliation is to ultimately reconcile the revenue requirement reflected in rates for each calendar year, beginning with the calendar year in which the utility files its performance-based formula rate tariff pursuant to subsection (c) of this Section, with what the revenue requirement determined using a year-end rate base for the applicable calendar year would have been had the actual cost information for the applicable calendar year been available at the filing date.

(2) The new charges shall take effect beginning on the first billing day of the following January billing period and remain in effect through the last billing day of the next December billing period regardless of whether the Commission enters upon a hearing pursuant to this subsection (d).

(3) The filing shall include relevant and necessary data and documentation for the applicable rate year that is consistent with the Commission's rules applicable to a filing for a general increase in rates or any rules adopted by the Commission to implement this Section. Normalization adjustments shall not be required. Notwithstanding any other provision of this Section or Act or any rule or other requirement adopted by the Commission, a participating utility that is a combination utility with more than one rate zone shall not be required to file a separate set of such data and documentation for each rate zone and may combine such data and documentation into a single set of schedules.

Within 45 days after the utility files its annual update of cost inputs to the performance-based formula rate, the Commission shall have the authority, either upon complaint or its own initiative, but with reasonable notice, to enter upon a hearing concerning the prudence and reasonableness of the costs incurred by the utility to be recovered during the applicable rate year that are reflected in the inputs to the performance-based formula rate derived from the utility's FERC Form 1. During the course of the hearing, each objection shall be stated with particularity and evidence provided in support thereof, after which the utility shall have the opportunity to rebut the evidence. Discovery shall be allowed consistent with the Commission's Rules of Practice, which Rules shall be enforced by the Commission or the assigned administrative law judge. The Commission shall apply the same evidentiary standards, including, but not limited to, those concerning the prudence and reasonableness of the costs incurred by the utility, in the hearing as it would apply in a hearing to review a filing for a general increase in rates under Article IX of this Act. The Commission shall not, however, have the authority in a proceeding under this subsection (d) to consider or order any changes to the structure or protocols of the performance-based formula rate approved pursuant to subsection (c) of this Section. In a proceeding under this subsection (d), the Commission shall enter its order no later than the earlier of 240 days after the utility's filing of its annual update of cost inputs to the performance-based formula rate or December 31. The Commission's determinations of the prudence and reasonableness of the costs incurred for the applicable calendar year shall be final upon entry of the Commission's order and shall not be subject to reopening, reexamination, or collateral attack in any other Commission proceeding, case, docket, order, rule or regulation, provided, however, that nothing in this subsection (d) shall prohibit a party from petitioning the Commission to rehear or appeal to the courts the order pursuant to the provisions of this Act.

In the event the Commission does not, either upon complaint or its own initiative, enter upon a hearing within 45 days after the utility files the annual update of cost inputs to its performance-based formula rate, then the costs incurred for the applicable calendar year shall be deemed prudent and reasonable, and the filed charges shall not be subject to reopening, reexamination, or collateral attack in any other proceeding, case, docket, order, rule, or regulation.

A participating utility's first filing of the updated cost inputs, and any Commission investigation of such inputs pursuant to this subsection (d) shall proceed notwithstanding the fact that the Commission's investigation under subsection (c) of this Section is still pending and notwithstanding any other law, order, rule, or Commission practice to the contrary.

(e) Nothing in subsections (c) or (d) of this Section shall prohibit the Commission from investigating, or a participating utility from filing, revenue-neutral tariff changes related to rate design of a performance-based formula rate that has been placed into effect for the utility. Following approval of a participating utility's performance-based formula rate tariff pursuant to subsection (c) of this Section, the utility shall make a filing with the Commission within one year after the effective date of the performance-based formula rate tariff that proposes changes to the tariff to incorporate the findings of any final rate design orders of the Commission applicable to the participating utility and entered subsequent to the Commission's approval of the tariff. The Commission shall, after notice and hearing, enter its order approving, or approving with modification, the proposed changes to the performance-based formula rate tariff within 240 days after the utility's filing. Following such approval, the utility shall make a filing with the Commission during each subsequent 3-year period that either proposes revenue-neutral tariff changes or re-files the existing tariffs without change, which shall present the Commission with an opportunity to suspend the tariffs and consider revenue-neutral tariff changes related to rate design.

(f) Within 30 days after the filing of a tariff pursuant to subsection (c) of this Section, each participating utility shall develop and file with the Commission multi-year metrics designed to achieve, ratably (i.e., in equal segments) over a 10-year period, improvement over baseline performance values as follows:

(1) Twenty percent improvement in the System Average Interruption Frequency Index, using a baseline of the average of the data from 2001 through 2010.

(2) Fifteen percent improvement in the system Customer Average Interruption Duration Index, using a baseline of the average of the data from 2001 through 2010.

(3) For a participating utility other than a combination utility, 20% improvement in the System Average Interruption Frequency Index for its Southern Region, using a baseline of the average of the data from 2001 through 2010. For purposes of this paragraph (3), Southern Region shall have the meaning set forth in the participating utility's most recent report filed pursuant to Section 16-125 of this Act.

(3.5) For a participating utility other than a combination utility, 20% improvement in the System Average Interruption Frequency Index for its Northeastern Region, using a baseline of the average of the data from 2001 through 2010. For purposes of this paragraph (3.5), Northeastern Region shall have the meaning set forth in the participating utility's most recent report filed pursuant to Section 16-125 of this Act.

(4) Seventy-five percent improvement in the total number of customers who exceed the service reliability targets as set forth in subparagraphs (A) through (C) of paragraph (4) of subsection (b) of 83 Ill. Adm. Code 411.140 as of May 1, 2011, using 2010 as the baseline year.

(5) Reduction in issuance of estimated electric bills: 90% improvement for a participating utility other than a combination utility, and 56% improvement for a participating utility that is a combination utility, using a baseline of the average number of estimated bills for the years 2008 through 2010.

(6) Consumption on inactive meters: 90% improvement for a participating utility other than a combination utility, and 56% improvement for a participating utility that is a combination utility, using a baseline of the average unbilled kilowatthours for the years 2009 and 2010.

(7) Unaccounted for energy: 50% improvement for a participating utility other than a combination utility using a baseline of the non-technical line loss unaccounted for energy kilowatthours for the year 2009.

(8) Uncollectible expense: reduce uncollectible expense by at least $30,000,000 for a participating utility other than a combination utility and by at least $3,500,000 for a participating utility that is a combination utility, using a baseline of the average uncollectible expense for the years 2008 through 2010.

(9) Opportunities for minority-owned and female-owned business enterprises: design a performance metric regarding the creation of opportunities for minority-owned and female-owned business enterprises consistent with State and federal law using a base performance value of the percentage of the participating utility's capital expenditures that were paid to minority-owned and female-owned business enterprises in 2010.

The definitions set forth in 83 Ill. Adm. Code 411.20 as of May 1, 2011 shall be used for purposes of calculating performance under paragraphs (1) through (3.5) of this subsection (f), provided, however, that the participating utility may exclude up to 9 extreme weather event days from such calculation for each year, and provided further that the participating utility shall exclude 9 extreme weather event days when calculating each year of the baseline period to the extent that there are 9 such days in a given year of the baseline period. For purposes of this Section, an extreme weather event day is a 24-hour calendar day (beginning at 12:00 a.m. and ending at 11:59 p.m.) during which any weather event (e.g., storm, tornado) caused interruptions for 10,000 or more of the participating utility's customers for 3 hours or more. If there are more than 9 extreme weather event days in a year, then the utility may choose no more than 9 extreme weather event days to exclude, provided that the same extreme weather event days are excluded from each of the calculations performed under paragraphs (1) through (3.5) of this subsection (f).

The metrics shall include incremental performance goals for each year of the 10-year period, which shall be designed to demonstrate that the utility is on track to achieve the performance goal in each category at the end of the 10-year period. The utility shall elect when the 10-year period shall commence for the metrics set forth in subparagraphs (1) through (4) and (9) of this subsection (f), provided that it begins no later than 14 months following the date on which the utility begins investing pursuant to subsection (b) of this Section, and when the 10-year period shall commence for the metrics set forth in subparagraphs (5) through (8) of this subsection (f), provided that it begins no later than 14 months following the date on which the Commission enters its order approving the utility's Advanced Metering Infrastructure Deployment Plan pursuant to subsection (c) of Section 16-108.6 of this Act.

The metrics and performance goals set forth in subparagraphs (5) through (8) of this subsection (f) are based on the assumptions that the participating utility may fully implement the technology described in subsection (b) of this Section, including utilizing the full functionality of such technology and that there is no requirement for personal on-site notification. If the utility is unable to meet the metrics and performance goals set forth in subparagraphs (5) through (8) of this subsection (f) for such reasons, and the Commission so finds after notice and hearing, then the utility shall be excused from compliance, but only to the limited extent achievement of the affected metrics and performance goals was hindered by the less than full implementation.

(f-5) The financial penalties applicable to the metrics described in subparagraphs (1) through (8) of subsection (f) of this Section, as applicable, shall be applied through an adjustment to the participating utility's return on equity of no more than a total of 30 basis points in each of the first 3 years, of no more than a total of 34 basis points in each of the 3 years thereafter, and of no more than a total of 38 basis points in each of the 4 years thereafter, as follows:

(1) With respect to each of the incremental annual performance goals established pursuant to paragraph (1) of subsection (f) of this Section,

(A) for each year that a participating utility other than a combination utility does not achieve the annual goal, the participating utility's return on equity shall be reduced as follows: during years 1 through 3, by 5 basis points; during years 4 through 6, by 6 basis points; and during years 7 through 10, by 7 basis points; and

(B) for each year that a participating utility that is a combination utility does not achieve the annual goal, the participating utility's return on equity shall be reduced as follows: during years 1 through 3, by 10 basis points; during years 4 through 6, by 12 basis points; and during years 7 through 10, by 14 basis points.

(2) With respect to each of the incremental annual performance goals established pursuant to paragraph (2) of subsection (f) of this Section, for each year that the participating utility does not achieve each such goal, the participating utility's return on equity shall be reduced as follows: during years 1 through 3, by 5 basis points; during years 4 through 6, by 6 basis points; and during years 7 through 10, by 7 basis points.

(3) With respect to each of the incremental annual performance goals established pursuant to paragraphs (3) and (3.5) of subsection (f) of this Section, for each year that a participating utility other than a combination utility does not achieve both such goals, the participating utility's return on equity shall be reduced as follows: during years 1 through 3, by 5 basis points; during years 4 through 6, by 6 basis points; and during years 7 through 10, by 7 basis points.

(4) With respect to each of the incremental annual performance goals established pursuant to paragraph (4) of subsection (f) of this Section, for each year that the participating utility does not achieve each such goal, the participating utility's return on equity shall be reduced as follows: during years 1 through 3, by 5 basis points; during years 4 through 6, by 6 basis points; and during years 7 through 10, by 7 basis points.

(5) With respect to each of the incremental annual performance goals established pursuant to subparagraph (5) of subsection (f) of this Section, for each year that the participating utility does not achieve at least 95% of each such goal, the participating utility's return on equity shall be reduced by 5 basis points for each such unachieved goal.

(6) With respect to each of the incremental annual performance goals established pursuant to paragraphs (6), (7), and (8) of subsection (f) of this Section, as applicable, which together measure non-operational customer savings and benefits relating to the implementation of the Advanced Metering Infrastructure Deployment Plan, as defined in Section 16-108.6 of this Act, the performance under each such goal shall be calculated in terms of the percentage of the goal achieved. The percentage of goal achieved for each of the goals shall be aggregated, and an average percentage value calculated, for each year of the 10-year period. If the utility does not achieve an average percentage value in a given year of at least 95%, the participating utility's return on equity shall be reduced by 5 basis points.

The financial penalties shall be applied as described in this subsection (f-5) for the 12-month period in which the deficiency occurred through a separate tariff mechanism, which shall be filed by the utility together with its metrics. In the event the formula rate tariff established pursuant to subsection (c) of this Section terminates, the utility's obligations under subsection (f) of this Section and this subsection (f-5) shall also terminate, provided, however, that the tariff mechanism established pursuant to subsection (f) of this Section and this subsection (f-5) shall remain in effect until any penalties due and owing at the time of such termination are applied.

The Commission shall, after notice and hearing, enter an order within 120 days after the metrics are filed approving, or approving with modification, a participating utility's tariff or mechanism to satisfy the metrics set forth in subsection (f) of this Section. On June 1 of each subsequent year, each participating utility shall file a report with the Commission that includes, among other things, a description of how the participating utility performed under each metric and an identification of any extraordinary events that adversely impacted the utility's performance. Whenever a participating utility does not satisfy the metrics required pursuant to subsection (f) of this Section, the Commission shall, after notice and hearing, enter an order approving financial penalties in accordance with this subsection (f-5). The Commission-approved financial penalties shall be applied beginning with the next rate year. Nothing in this Section shall authorize the Commission to reduce or otherwise obviate the imposition of financial penalties for failing to achieve one or more of the metrics established pursuant to subparagraphs (1) through (4) of subsection (f) of this Section.

(g) On or before July 31, 2014, each participating utility shall file a report with the Commission that sets forth the average annual increase in the average amount paid per kilowatthour for residential eligible retail customers, exclusive of the effects of energy efficiency programs, comparing the 12-month period ending May 31, 2012; the 12-month period ending May 31, 2013; and the 12-month period ending May 31, 2014. For a participating utility that is a combination utility with more than one rate zone, the weighted average aggregate increase shall be provided. The report shall be filed together with a statement from an independent auditor attesting to the accuracy of the report. The cost of the independent auditor shall be borne by the participating utility and shall not be a recoverable expense. "The average amount paid per kilowatthour" shall be based on the participating utility's tariffed rates actually in effect and shall not be calculated using any hypothetical rate or adjustments to actual charges (other than as specified for energy efficiency) as an input.

In the event that the average annual increase exceeds 2.5% as calculated pursuant to this subsection (g), then Sections 16-108.5, 16-108.6, 16-108.7, and 16-108.8 of this Act, other than this subsection, shall be inoperative as they relate to the utility and its service area as of the date of the report due to be submitted pursuant to this subsection and the utility shall no longer be eligible to annually update the performance-based formula rate tariff pursuant to subsection (d) of this Section. In such event, the then current rates shall remain in effect until such time as new rates are set pursuant to Article IX of this Act, subject to retroactive adjustment, with interest, to reconcile rates charged with actual costs, and the participating utility's voluntary commitments and obligations under subsection (b) of this Section shall immediately terminate, except for the utility's obligation to pay an amount already owed to the fund for training grants pursuant to a Commission order issued under subsection (b) of this Section.

In the event that the average annual increase is 2.5% or less as calculated pursuant to this subsection (g), then the performance-based formula rate shall remain in effect as set forth in this Section.

For purposes of this Section, the amount per kilowatthour means the total amount paid for electric service expressed on a per kilowatthour basis, and the total amount paid for electric service includes without limitation amounts paid for supply, transmission, distribution, surcharges, and add-on taxes exclusive of any increases in taxes or new taxes imposed after October 26, 2011 (the effective date of Public Act 97-616). For purposes of this Section, "eligible retail customers" shall have the meaning set forth in Section 16-111.5 of this Act.

The fact that this Section becomes inoperative as set forth in this subsection shall not be construed to mean that the Commission may reexamine or otherwise reopen prudence or reasonableness determinations already made.

(h) By December 31, 2017, the Commission shall prepare and file with the General Assembly a report on the infrastructure program and the performance-based formula rate. The report shall include the change in the average amount per kilowatthour paid by residential customers between June 1, 2011 and May 31, 2017. If the change in the total average rate paid exceeds 2.5% compounded annually, the Commission shall include in the report an analysis that shows the portion of the change due to the delivery services component and the portion of the change due to the supply component of the rate. The report shall include separate sections for each participating utility.

The provisions of Sections 16-108.6, 16-108.7, and 16-108.8 of this Act and the provisions of this Section, other than this subsection (h) and subsection (i) of this Section, are inoperative after December 31, 2022 for every participating utility, after which time a participating utility shall no longer be eligible to annually update the performance-based formula rate tariff pursuant to subsection (d) of this Section. At such time, the then current rates shall remain in effect until such time as new rates are set pursuant to Article IX of this Act, subject to retroactive adjustment, with interest, to reconcile rates charged with actual costs.

The fact that this Section becomes inoperative as set forth in this subsection shall not be construed to mean that the Commission may reexamine or otherwise reopen prudence or reasonableness determinations already made.

(i) The provisions of this subsection (i) are inoperative after December 31, 2027.

While an electric utility may use, develop, and maintain broadband systems and the delivery of broadband services, Voice over Internet Protocol (VoIP) services, telecommunications services, and cable or video programming services for use in providing delivery services to its retail customers, an electric utility is prohibited from providing to its retail customers broadband services, Voice over Internet Protocol (VoIP) services, telecommunications services, or cable or video programming services, unless they are part of a service directly related to delivery services, and from recovering the costs of such offerings from retail customers.

Furthermore, an electric utility in a county with a population of 3,000,000 or more shall not authorize any other person or grant any other person the right, by agreement, lease, license, or otherwise, to access, control, use, or operate that electric utility's infrastructure, facilities, or assets of any kind or to deliver or provide to that electric utility's customers or any other person's customers, broadband services, Voice over Internet Protocol (VoIP) services, telecommunications services, or cable or video programming services.

However, notwithstanding the prohibitions set forth in this Section, an electric utility in a county with a population of 3,000,000 or more may authorize or grant another person the right to access or use the electric utility's infrastructure, facilities, or assets, including, but not limited to, middle mile infrastructure, to facilitate the delivery of broadband services to Illinois residential and commercial customers on the condition that the access to and use of that electric utility's infrastructure, facilities, and assets (A) be granted on a non-discriminatory, non-exclusive, and competitively neutral basis; and (B) comply with all other State and federal laws, rules, and regulations, including, but not limited to, all applicable safety codes and requirements. If there is any dispute regarding the terms, rates, or conditions of access to or use of that electric utility's infrastructure, facilities, and assets to facilitate the delivery of broadband services to Illinois residential and commercial customers, the Commission, upon the petition of any party, shall hear and decide the dispute in accordance with the Commission's Rules of Practice (83 Ill. Adm. Code Part 200).

Nothing in this amendatory Act of the 103rd General Assembly shall be construed to authorize any electric utility in a county with a population of 3,000,000 or more to consent to, or grant to, any other person by agreement, lease, license, or otherwise, the right to access, occupy, or use any infrastructure, facility, easement, or asset of any kind not owned by the electric utility.

Nothing in this amendatory Act of the 103rd General Assembly shall be construed to alter or diminish the rights or obligations of any person under, nor shall it be deemed to conflict with, the federal Pole Attachment Act (47 U.S.C. 224).

As used in this subsection (i):

"Broadband services" means the services that are used to deliver to subscribers a high-speed service connection to the public Internet that is capable of supporting, in at least one direction, a speed in excess of 200 kilobits per second (kbps) to the network demarcation point at the subscribers' premises.

"Electric utility" has the meaning set forth in Section 16-102.

"Middle mile infrastructure" has the meaning provided in Section 60401 of the federal Infrastructure Investment and Jobs Act (47 U.S.C. 1741).

(j) Nothing in this Section is intended to legislatively overturn the opinion issued in Commonwealth Edison Co. v. Ill. Commerce Comm'n, Nos. 2-08-0959, 2-08-1037, 2-08-1137, 1-08-3008, 1-08-3030, 1-08-3054, 1-08-3313 cons. (Ill. App. Ct. 2d Dist. Sept. 30, 2010). Public Act 97-616 shall not be construed as creating a contract between the General Assembly and the participating utility, and shall not establish a property right in the participating utility.

(k) The changes made in subsections (c) and (d) of this Section by Public Act 98-15 are intended to be a restatement and clarification of existing law, and intended to give binding effect to the provisions of House Resolution 1157 adopted by the House of Representatives of the 97th General Assembly and Senate Resolution 821 adopted by the Senate of the 97th General Assembly that are reflected in paragraph (3) of this subsection. In addition, Public Act 98-15 preempts and supersedes any final Commission orders entered in Docket Nos. 11-0721, 12-0001, 12-0293, and 12-0321 to the extent inconsistent with the amendatory language added to subsections (c) and (d).

(1) No earlier than 5 business days after May 22, 2013 (the effective date of Public Act 98-15), each participating utility shall file any tariff changes necessary to implement the amendatory language set forth in subsections (c) and (d) of this Section by Public Act 98-15 and a revised revenue requirement under the participating utility's performance-based formula rate. The Commission shall enter a final order approving such tariff changes and revised revenue requirement within 21 days after the participating utility's filing.

(2) Notwithstanding anything that may be to the contrary, a participating utility may file a tariff to retroactively recover its previously unrecovered actual costs of delivery service that are no longer subject to recovery through a reconciliation adjustment under subsection (d) of this Section. This retroactive recovery shall include any derivative adjustments resulting from the changes to subsections (c) and (d) of this Section by Public Act 98-15. Such tariff shall allow the utility to assess, on current customer bills over a period of 12 monthly billing periods, a charge or credit related to those unrecovered costs with interest at the utility's weighted average cost of capital during the period in which those costs were unrecovered. A participating utility may file a tariff that implements a retroactive charge or credit as described in this paragraph for amounts not otherwise included in the tariff filing provided for in paragraph (1) of this subsection (k). The Commission shall enter a final order approving such tariff within 21 days after the participating utility's filing.

(3) The tariff changes described in paragraphs (1) and (2) of this subsection (k) shall relate only to, and be consistent with, the following provisions of Public Act 98-15: paragraph (2) of subsection (c) regarding year-end capital structure, subparagraph (D) of paragraph (4) of subsection (c) regarding pension assets, and subsection (d) regarding the reconciliation components related to year-end rate base and interest calculated at a rate equal to the utility's weighted average cost of capital.

(4) Nothing in this subsection is intended to effect a dismissal of or otherwise affect an appeal from any final Commission orders entered in Docket Nos. 11-0721, 12-0001, 12-0293, and 12-0321 other than to the extent of the amendatory language contained in subsections (c) and (d) of this Section of Public Act 98-15.

(l) Each participating utility shall be deemed to have been in full compliance with all requirements of subsection (b) of this Section, subsection (c) of this Section, Section 16-108.6 of this Act, and all Commission orders entered pursuant to Sections 16-108.5 and 16-108.6 of this Act, up to and including May 22, 2013 (the effective date of Public Act 98-15). The Commission shall not undertake any investigation of such compliance and no penalty shall be assessed or adverse action taken against a participating utility for noncompliance with Commission orders associated with subsection (b) of this Section, subsection (c) of this Section, and Section 16-108.6 of this Act prior to such date. Each participating utility other than a combination utility shall be permitted, without penalty, a period of 12 months after such effective date to take actions required to ensure its infrastructure investment program is in compliance with subsection (b) of this Section and with Section 16-108.6 of this Act. Provided further, the following subparagraphs shall apply to a participating utility other than a combination utility:

(A) if the Commission has initiated a proceeding pursuant to subsection (e) of Section 16-108.6 of this Act that is pending as of May 22, 2013 (the effective date of Public Act 98-15), then the order entered in such proceeding shall, after notice and hearing, accelerate the commencement of the meter deployment schedule approved in the final Commission order on rehearing entered in Docket No. 12-0298;

(B) if the Commission has entered an order pursuant to subsection (e) of Section 16-108.6 of this Act prior to May 22, 2013 (the effective date of Public Act 98-15) that does not accelerate the commencement of the meter deployment schedule approved in the final Commission order on rehearing entered in Docket No. 12-0298, then the utility shall file with the Commission, within 45 days after such effective date, a plan for accelerating the commencement of the utility's meter deployment schedule approved in the final Commission order on rehearing entered in Docket No. 12-0298; the Commission shall reopen the proceeding in which it entered its order pursuant to subsection (e) of Section 16-108.6 of this Act and shall, after notice and hearing, enter an amendatory order that approves or approves as modified such accelerated plan within 90 days after the utility's filing; or

(C) if the Commission has not initiated a proceeding pursuant to subsection (e) of Section 16-108.6 of this Act prior to May 22, 2013 (the effective date of Public Act 98-15), then the utility shall file with the Commission, within 45 days after such effective date, a plan for accelerating the commencement of the utility's meter deployment schedule approved in the final Commission order on rehearing entered in Docket No. 12-0298 and the Commission shall, after notice and hearing, approve or approve as modified such plan within 90 days after the utility's filing.

Any schedule for meter deployment approved by the Commission pursuant to this subsection (l) shall take into consideration procurement times for meters and other equipment and operational issues. Nothing in Public Act 98-15 shall shorten or extend the end dates for the 5-year or 10-year periods set forth in subsection (b) of this Section or Section 16-108.6 of this Act. Nothing in this subsection is intended to address whether a participating utility has, or has not, satisfied any or all of the metrics and performance goals established pursuant to subsection (f) of this Section.

(m) The provisions of Public Act 98-15 are severable under Section 1.31 of the Statute on Statutes.

(Source: P.A. 102-1031, eff. 5-27-22; 103-154, eff. 6-30-23; 103-679, eff. 7-19-24.)

(220 ILCS 5/16-108.6)

Sec. 16-108.6. Provisions relating to Smart Grid Advanced Metering Infrastructure Deployment Plan.

(a) For purposes of this Section and Sections 16-108.7 and 16-108.8 of this Act:

"Advanced Metering Infrastructure" or "AMI" means the communications hardware and software and associated system software that enables Smart Grid functions by creating a network between advanced meters and utility business systems and allowing collection and distribution of information to customers and other parties in addition to providing information to the utility itself.

"Cost-beneficial" means a determination that the benefits of a participating utility's Smart Grid AMI Deployment Plan exceed the costs of the Smart Grid AMI Deployment Plan as initially filed with the Commission or as subsequently modified by the Commission. This standard is met if the present value of the total benefits of the Smart Grid AMI Deployment Plan exceeds the present value of the total costs of the Smart Grid AMI Deployment Plan. The total cost shall include all utility costs reasonably associated with the Smart Grid AMI Deployment Plan. The total benefits shall include the sum of avoided electricity costs, including avoided utility operational costs, avoided consumer power, capacity, and energy costs, and avoided societal costs associated with the production and consumption of electricity, as well as other societal benefits, including the greater integration of renewable and distributed power resources, reductions in the emissions of harmful pollutants and associated avoided health-related costs, other benefits associated with energy efficiency measures, demand-response activities, and the enabling of greater penetration of alternative fuel vehicles.

"Participating utility" has the meaning set forth in Section 16-108.5 of this Act.

"Smart Grid" means investments and policies that together promote one or more of the following goals:

(1) Increased use of digital information and controls technology to improve reliability, security, and efficiency of the electric grid.

(2) Dynamic optimization of grid operations and resources, with full cyber security.

(3) Deployment and integration of distributed resources and generation, including renewable resources.

(4) Development and incorporation of demand-response, demand-side resources, and energy efficiency resources.

(5) Deployment of "smart" technologies (real-time, automated, interactive technologies that optimize the physical operation of appliances and consumer devices) for metering, communications concerning grid operations and status, and distribution automation.

(6) Integration of "smart" appliances and consumer devices.

(7) Deployment and integration of advanced electricity storage and peak-shaving technologies, including plug-in electric and hybrid electric vehicles, thermal-storage air conditioning and renewable energy generation.

(8) Provision to consumers of timely information and control options.

(9) Development of open access standards for communication and interoperability of appliances and equipment connected to the electric grid, including the infrastructure serving the grid.

(10) Identification and lowering of unreasonable or unnecessary barriers to adoption of Smart Grid technologies, practices, services, and business models that support energy efficiency, demand-response, and distributed generation.

"Smart Grid Advisory Council" means the group of stakeholders formed pursuant to subsection (b) of this Section for the purposes of advising and working with participating utilities on the development and implementation of a Smart Grid Advanced Metering Infrastructure Deployment Plan.

"Smart Grid electric system upgrades" means any of the following:

(1) metering devices, sensors, control devices, and other devices integrated with and attached to an electric utility system that are capable of engaging in Smart Grid functions;

(2) other monitoring and communications devices that enable Smart Grid functions, including, but not limited to, distribution automation;

(3) software that enables devices or computers to engage in Smart Grid functions;

(4) associated cyber secure data communication network, including enhancements to cyber-security technologies and measures;

(5) substation micro-processor relay upgrades;

(6) devices that allow electric or hybrid-electric vehicles to engage in Smart Grid functions; or

(7) devices that enable individual consumers to incorporate distributed and micro-generation.

"Smart Grid electric system upgrades" does not include expenditures for: (1) electricity generation, transmission, or distribution infrastructure or equipment that does not directly relate to or support installing, implementing or enabling Smart Grid functions; (2) physical interconnection of generators or other devices to the grid except those that are directly related to enabling Smart Grid functions; or (3) ongoing or routine operation, billing, customer relations, security, and maintenance.

"Smart Grid functions" means:

(1) the ability to develop, store, send, and receive digital information concerning or enabling grid operations, electricity use, costs, prices, time of use, nature of use, storage, or other information relevant to device, grid, or utility operations, to or from or by means of the electric utility system through one or a combination of devices and technologies;

(2) the ability to develop, store, send, and receive digital information concerning electricity use, costs, prices, time of use, nature of use, storage, or other information relevant to device, grid, or utility operations to or from a computer or other control device;

(3) the ability to measure or monitor electricity use as a function of time of day, power quality characteristics such as voltage level, current, cycles per second, or source or type of generation and to store, synthesize, or report that information by digital means;

(4) the ability to sense and localize disruptions or changes in power flows on the grid and communicate such information instantaneously and automatically for purposes of enabling automatic protective responses to sustain reliability and security of grid operations;

(5) the ability to detect, prevent, communicate with regard to, respond to, or recover from system security threats, including cyber-security threats and terrorism, using digital information, media, and devices;

(6) the ability of any device or machine to respond to signals, measurements, or communications automatically or in a manner programmed by its owner or operator without independent human intervention;

(7) the ability to use digital information to operate functionalities on the electric utility grid that were previously electro-mechanical or manual;

(8) the ability to use digital controls to manage and modify electricity demand, enable congestion management, assist in voltage control, provide operating reserves, and provide frequency regulation; or

(9) the ability to integrate electric plug-in vehicles, distributed generation, and storage in a safe and cost-effective manner on the electric grid.

(b) Within 30 days after the effective date of this amendatory Act of the 97th General Assembly, the Smart Grid Advisory Council shall be established, which shall consist of 9 total voting members with each member possessing either technical, business or consumer expertise in Smart Grid issues, 5 of whom shall be appointed by the Governor, one of whom shall be appointed by the Speaker of the House, one of whom shall be appointed by the Minority Leader of the House, one of whom shall be appointed by the President of the Senate, and one of whom shall be appointed by the Minority Leader of the Senate. Of the Governor's 5 appointments: (i) at least one must represent a non-profit membership organization whose mission is to cultivate innovation and technology-based economic development in Illinois by fostering public-private partnerships to develop and execute research and development projects, advocating for funding for research and development initiatives, and collaborating with public and private partners to attract and retain research and development resources and talent in Illinois; (ii) at least one must represent a non-profit public body corporate and politic created by law that has a duty to represent and protect residential utility consumers in Illinois; (iii) at least one must represent a membership organization that represents the interests of individuals and companies that own, operate, manage, and service commercial buildings in a municipality with a population of 1,000,000 or more inhabitants; and (iv) at least one must represent an alternative retail electric supplier that has obtained a certificate of service authority pursuant to Section 16-115 of this Act and that is not an affiliate of a participating utility prior to one year after the effective date of this amendatory Act of the 97th General Assembly.

The Governor shall designate one of the members of the Council to serve as chairman, and that person shall serve as the chairman at the pleasure of the Governor. The members shall not be compensated for serving on the Smart Grid Advisory Council. The Smart Grid Advisory Council shall have the following duties:

(1) Serve as an advisor to participating utilities subject to this Section and in the manner described in this Section, and the recommendations provided by the Council, although non-binding, shall be considered by the utilities.

(2) Serve as trustees of the trust or foundation established pursuant to Section 16-108.7 of this Act with the duties enumerated thereunder.

(c) After consultation with the Smart Grid Advisory Council, each participating utility shall file a Smart Grid Advanced Metering Infrastructure Deployment Plan ("AMI Plan") with the Commission within 180 days after the effective date of this amendatory Act of the 97th General Assembly or by November 1, 2011, whichever is later, or in the case of a combination utility as defined in Section 16-108.5, by April 1, 2012, provided that a participating utility shall not file its plan until the evaluation report on the Pilot Program described in this subsection (c) is issued. The AMI Plan shall provide for investment over a 10-year period that is sufficient to implement the AMI Plan across its entire service territory in a manner that is consistent with subsection (b) of Section 16-108.5 of this Act. The AMI Plan shall contain:

(1) the participating utility's Smart Grid AMI vision statement that is consistent with the goal of developing a cost-beneficial Smart Grid;

(2) a statement of Smart Grid AMI strategy that includes a description of how the utility evaluates and prioritizes technology choices to create customer value, including a plan to enhance and enable customers' ability to take advantage of Smart Grid functions beginning at the time an account has billed successfully on the AMI network;

(3) a deployment schedule and plan that includes deployment of AMI to all customers for a participating utility other than a combination utility, and to 62% of all customers for a participating utility that is a combination utility;

(4) annual milestones and metrics for the purposes of measuring the success of the AMI Plan in enabling Smart Grid functions; and enhancing consumer benefits from Smart Grid AMI; and

(5) a plan for the consumer education to be implemented by the participating utility.

The AMI Plan shall be fully consistent with the standards of the National Institute of Standard and Technology (NIST) for Smart Grid interoperability that are in effect at the time the participating utility files its AMI Plan, shall include open standards and internet protocol to the maximum extent possible consistent with cyber security, and shall maximize, to the extent possible, a flexible smart meter platform that can accept remote device upgrades and contain sufficient internal memory capacity for additional storage capabilities, functions and services without the need for physical access to the meter.

The AMI Plan shall secure the privacy of personal information and establish the right of consumers to consent to the disclosure of personal energy information to third parties through electronic, web-based, and other means in accordance with State and federal law and regulations regarding consumer privacy and protection of consumer data.

After notice and hearing, the Commission shall, within 60 days of the filing of an AMI Plan, issue its order approving, or approving with modification, the AMI Plan if the Commission finds that the AMI Plan contains the information required in paragraphs (1) through (5) of this subsection (c) and further finds that the implementation of the AMI Plan will be cost-beneficial consistent with the principles established through the Illinois Smart Grid Collaborative, giving weight to the results of any Commission-approved pilot designed to examine the benefits and costs of AMI deployment. A participating utility's decision to invest pursuant to an AMI Plan approved by the Commission shall not be subject to prudence reviews in subsequent Commission proceedings. Nothing in this subsection (c) is intended to limit the Commission's ability to review the reasonableness of the costs incurred under the AMI Plan. A participating utility shall be allowed to recover the reasonable costs it incurs in implementing a Commission-approved AMI Plan, including the costs of retired meters, and may recover such costs through its tariffs, including the performance-based formula rate tariff approved pursuant to subsection (c) of Section 16-108.5 of this Act.

(d) The AMI Plan shall secure the privacy of the customer's personal information. "Personal information" for this purpose consists of the customer's name, address, telephone number, and other personally identifying information, as well as information about the customer's electric usage. Electric utilities, their contractors or agents, and any third party who comes into possession of such personal information by virtue of working on Smart Grid technology shall not disclose such personal information to be used in mailing lists or to be used for other commercial purposes not reasonably related to the conduct of the utility's business. Electric utilities shall comply with the consumer privacy requirements of the Personal Information Protection Act. In the event a participating utility receives revenues from the sale of information obtained through Smart Grid technology that is not personal information, the participating utility shall use such revenues to offset the revenue requirement.

(e) On April 1 of each year beginning in 2013 and after consultation with the Smart Grid Advisory Council, each participating utility shall submit a report regarding the progress it has made toward completing implementation of its AMI Plan. This report shall:

(1) describe the AMI investments made during the prior 12 months and the AMI investments planned to be made in the following 12 months;

(2) provide sufficient detail to determine the utility's progress in meeting the metrics and milestones identified by the utility in its AMI Plan; and

(3) identify any updates to the AMI Plan.

Within 21 days after the utility files its annual report, the Commission shall have authority, either upon complaint or its own initiative, but with reasonable notice, to enter upon an investigation regarding the utility's progress in implementing the AMI Plan as described in paragraph (1) of this subsection (e). If the Commission finds, after notice and hearing, that the participating utility's progress in implementing the AMI Plan is materially deficient for the given plan year, then the Commission shall issue an order requiring the participating utility to devise a corrective action plan, subject to Commission approval and oversight, to bring implementation back on schedule consistent with the AMI Plan. The Commission's order must be entered within 90 days after the utility files its annual report. If the Commission does not initiate an investigation within 21 days after the utility files its annual report, then the filing shall be deemed accepted by the Commission. The utility shall not be required to suspend implementation of its AMI Plan during any Commission investigation.

The participating utility's annual report regarding AMI Plan year 10 shall contain a statement verifying that the implementation of its AMI Plan is complete, provided, however, that if the utility is subject to a corrective action plan that extends the implementation period beyond 10 years, the utility shall include the verification statement in its final annual report. Following the date of a Commission order approving the final annual report or the date on which the final report is deemed accepted by the Commission, the utility's annual reporting obligations under this subsection (d) shall terminate, provided, however, that the utility shall have a continuing obligation to provide information, upon request, to the Commission and Smart Grid Advisory Council regarding the AMI Plan.

(f) Each participating utility shall pay a pro rata share, based on number of customers, of $5,000,000 per year to the trust or foundation established pursuant to Section 16-108.7 of this Act for each plan year of the AMI Plan, which shall be used for purposes of providing customer education regarding smart meters and related consumer-facing technologies and services and 70% of which shall be a recoverable expense; provided that other reasonable amounts expended by the utility for such consumer education shall not be subject to the 70% limitation of this subsection.

(g) Within 60 days after the Commission approves a participating utility's AMI Plan pursuant to subsection (c) of this Section, the participating utility, after consultation with the Smart Grid Advisory Council, shall file a proposed tariff with the Commission that offers an opt-in market-based peak time rebate program to all residential retail customers with smart meters that is designed to provide, in a competitively neutral manner, rebates to those residential retail customers that curtail their use of electricity during specific periods that are identified as peak usage periods. The total amount of rebates shall be the amount of compensation the utility obtains through markets or programs at the applicable regional transmission organization. The utility shall make all reasonable attempts to secure funding for the peak time rebate program through markets or programs at the applicable regional transmission organization. The rules and procedures for consumers to opt-in to the peak time rebate program shall include electronic sign-up, be designed to maximize participation, and be included on the utility's website. The Commission shall monitor the performance of programs established pursuant to this subsection (g) and shall order the termination or modification of a program if it determines that the program is not, after a reasonable period of time for development of at least 4 years, resulting in net benefits to the residential customers of the participating utility.

(h) If Section 16-108.5 of this Act becomes inoperative with respect to one or more participating utilities as set forth in subsection (g) or (h) of that Section, then Sections 16-108.5, 16-108.6, 16-108.7, and 16-108.8 of this Act shall become inoperative as to each affected utility and its service area on the same date as Section 16-108.5 becomes inoperative.

(Source: P.A. 97-616, eff. 10-26-11; 97-646, eff. 12-30-11.)

(220 ILCS 5/16-108.7)

Sec. 16-108.7. Illinois Science and Energy Innovation Trust.

(a) Within 90 days of the effective date of this amendatory Act of the 97th General Assembly, the members of the Smart Grid Advisory Council established pursuant to Section 16-108.6 of this Act, or a majority of the members thereof, shall cause to be established an Illinois science and energy innovation trust or foundation for the purposes of providing financial and technical support and assistance to entities, public or private, within the State of Illinois including, but not limited to, units of State and local government, educational and research institutions, corporations, and charitable, educational, environmental and community organizations, for programs and projects that support, encourage or utilize innovative technologies or other methods of modernizing the State's electric grid that will benefit the public by promoting economic development in Illinois. Such activities shall be supported through grants, loans, contracts, or other programs designed to assist and further benefit technological advances in the area of electric grid modernization and operation. The trust or foundation shall also be eligible for receipt of other energy and environmental grant opportunities, from public or private sources. The trust or foundation shall not be a governmental entity.

(b) Funds received by the trust or foundation pursuant to subsection (f) of Section 16-108.6 of this Act shall be used solely for the purpose of providing consumer education regarding smart meters and related consumer-facing technologies and services and the peak time rebate program described in subsection (g) of Section 16-108.6 of this Act. Thirty percent of such funds received from each participating utility shall be used by the trust or foundation for purposes of providing such education to each participating utility's low-income retail customers, including low-income senior citizens.

The trust or foundation shall use all funds received pursuant to subsection (f) of Section 16-108.6 of this Act in a manner that reflects the unique needs and characteristics of each participating utility's service territory and in proportion to each participating utility's payment.

(c) Such trust or foundation shall be governed by a declaration of trust or articles of incorporation and bylaws which shall, at a minimum, provide the following:

(1) There shall initially be 9 trustees of the trust or foundation, which shall consist of the members of the Smart Grid Advisory Council established pursuant to Section 16-108.6 of this Act. Subsequently, the participating utilities shall appoint one trustee and the Clean Energy Trust shall appoint one non-voting trustee who shall provide expertise regarding early stage investment in Smart Grid projects.

(2) All trustees shall be entitled to reimbursement for reasonable expenses incurred on behalf of the trust in the performance of their duties as trustees. All such reimbursements shall be paid out of the trust.

(3) Trustees shall be appointed within 60 days after the creation of the trust or foundation and shall serve for a term of 5 years commencing upon the date of their respective appointments, until their respective successors are appointed and qualified.

(4) A vacancy in the office of trustee shall be filled by the person holding the office responsible for appointing the trustee whose death or resignation creates the vacancy, and a trustee appointed to fill a vacancy shall serve the remainder of the term of the trustee whose resignation or death created the vacancy.

(5) The trust or foundation shall have an indefinite term and shall terminate at such time as no trust assets remain.

(6) The allocation and disbursement of funds for the various purposes for which the trust or foundation is established shall be determined by the trustees in accordance with the declaration of trust or the articles of incorporation and bylaws.

(7) The trust or foundation shall be authorized to employ an executive director and other employees, or contract management of the trust or foundation in its entirety to an outside organization found suitable by the trustees, to enter into leases, contracts and other obligations on behalf of the trust or foundation, and to incur expenses that the trustees deem necessary or appropriate for the fulfillment of the purposes for which the trust or foundation is established, provided, however, that salaries and administrative expenses incurred on behalf of the trust or foundation shall not exceed 3% of the trust's principal value, or $750,000, whichever is greater, in any given year. The trustees shall not be compensated by the trust or foundation.

(8) The trustees may create and appoint advisory boards or committees to assist them with the administration of the trust or foundation, and to advise and make recommendations to them regarding the contribution and disbursement of the trust or foundation funds.

(9) All funds dispersed by the trust or foundation for programs and projects to meet the objectives of the trust or foundation as enumerated in this Section shall be subject to a peer-review process as determined by the trustees. This process shall be designed to determine, in an objective and unbiased manner, those programs and projects that best fit the objectives of the trust or foundation. In each fiscal year the trustees shall determine, based solely on the information provided through the peer-review process, a budget for programs and projects for that fiscal year.

(10) The trustees shall administer a Smart Grid education fund from which it shall make grants to qualified not-for-profit organizations for the purpose of educating customers with regard to smart meters and related consumer-facing technologies and services. In making such grants the trust or foundation shall strongly encourage grantees to coordinate to the extent practicable and consider recommendations from the participating utilities regarding the development and implementation of customer education plans.

(11) One of the objectives of the trust or foundation is to remain self-funding. In order to meet this objective, the trustees may sign agreements with those entities receiving funding that provide for license fees, royalties, or other payments to the trust or foundation from such entities that receive support for their product development from the trust or foundation. Such payments, however, shall be contingent on the commercialization of such products, services, or technologies enabled by the funding provided by the trust or foundation.

(d) The trustees shall notify each participating utility as defined in Section 16-108.5 of this Act of the formation of the trust or foundation. Within 90 days after receipt of the notification, each participating utility that is not a combination utility as defined in Section 16-108.5 of this Act shall contribute $15,000,000 to the trust or foundation, and each participating utility that is a combination utility, as defined in Section 16-108.5 of this Act, shall contribute $7,500,000 to the trust or foundation established pursuant to this Section. Such contributions shall not be a recoverable expense.

(e) If Section 16-108.5 of this Act becomes inoperative with respect to one or more participating utilities as set forth in subsection (g) or (h) of that Section, then Sections 16-108.5, 16-108.6, 16-108.7, and 16-108.8 of this Act shall become inoperative as to each affected utility and its service area on the same date as Section 16-108.5 becomes inoperative.

(Source: P.A. 97-616, eff. 10-26-11; 97-646, eff. 12-30-11.)

(220 ILCS 5/16-108.8)

Sec. 16-108.8. Illinois Smart Grid test bed.

(a) Within 180 days after the effective date of this amendatory Act of the 97th General Assembly, each participating utility, as defined by Section 16-108.5 of this Act, shall create or otherwise designate a Smart Grid test bed, which may be located at one or more places within the utility's system, for the purposes of allowing for the testing of Smart Grid technologies. The objectives of this test bed shall be to:

(1) provide an open, unbiased opportunity for testing programs, technologies, business models, and other Smart Grid-related activities;

(2) provide on-grid locations for the testing of potentially innovative Smart Grid-related technologies and services, including but not limited to those funded by the trust or foundation established pursuant to Section 16-108.7 of this Act;

(3) facilitate testing of business models or services that help integrate Smart Grid-related technologies into the electric grid, especially those business models that may help promote new products and services for retail customers;

(4) offer opportunities to test and showcase Smart Grid technologies and services, especially those likely to support the economic development goals of the State of Illinois.

(b) The test bed shall reside in one or more locations on the participating utility's network. Such locations shall be chosen by the utility to maximize the opportunity for real-time and real-world testing of Smart Grid technologies and services taking into account the safety and security of the participating utility's grid and grid operations.

(c) The participating utility, with input from the Smart Grid Advisory Council established pursuant to Section 16-108.6 of this Act, shall, as part of its filing under subsection (b) of Section 16-108.5, include a plan for the creation, operation, and administration of the test bed. This plan shall address the following:

(1) how the utility proposes to comply with each of the objectives set forth in subsection (a) of this Section;

(2) the proposed location or locations of the test bed;

(3) the process by which the utility will receive, review, and qualify proposals to use the test bed;

(4) the criteria by which the utility proposes to qualify proposals to use the test bed, including, but not limited to, safety, reliability, security, customer data security, privacy, and economic development considerations;

(5) the engineering and operations support that the utility will provide to test bed users, including provision of customer data; and

(6) the estimated costs to establish, administer and promote the availability of the test bed.

(d) The test bed should be open to all qualified entities wishing to test programs, technologies, business models, and other Smart Grid-related activities, provided that the utility retains control of its grid and operations and may reject any programs, technologies, business models, and other Smart Grid-related activities that threaten the reliability, safety, security, or operations of its network, or that would threaten the security of customer-identifiable data in the judgment of the utility. The number of technologies and entities participating in the test bed at any time may be limited by the utility based on its determination of its ability to maintain a secure, safe, and reliable grid.

(e) At a minimum, the test bed shall have the ability to receive live signals from PJM Interconnection LLC or other applicable regional transmission organization, the ability to test new applications in a utility scale environment (to include ramp rate regulations for distributed wind and solar resources), critical peak price response, and market-based power dispatch.

(f) At the end of the fourth year of operation the test bed shall be subject to an independent evaluation to determine if the test bed is meeting the objectives of this Section or is likely to meet the objectives in the future. The evaluation shall include the performance of the utility as test bed operator. Subject to the findings, the utility and the trust or foundation established pursuant to Section 16-108.7 of this Act may choose to continue operating the test bed.

(g) The utility shall be entitled to recover all prudently incurred and reasonable costs associated with evaluation of proposals, engineering, construction, operation, and administration of the test bed through the performance-based formula rate tariff established pursuant to Section 16-108.5 of this Act.

(h) The utility is authorized to charge fees to users of the test bed that shall recover the costs associated with the incremental costs to the utility associated with administration of the test bed, provided, however, that any such fees collected by the utility shall be used to offset the costs to be recovered pursuant to subsection (g) of this Section.

(i) On a quarterly basis, the utility shall provide the trust or foundation established pursuant to Section 16-108.7 of this Act with a report summarizing test bed activities, customers, discoveries, and other information as shall be mutually deemed relevant.

(j) To the extent practicable, the utility and trust or foundation established pursuant to Section 16-108.7 of this Act shall jointly pursue resources that enhance the capabilities and capacity of the test bed.

(k) If Section 16-108.5 of this Act becomes inoperative with respect to one or more participating utilities as set forth in subsection (g) or (h) of that Section, then Sections 16-108.5, 16-108.6, 16-108.7, and 16-108.8 of this Act shall become inoperative as to each affected utility and its service area on the same date as Section 16-108.5 become inoperative.

(Source: P.A. 97-616, eff. 10-26-11.)

(220 ILCS 5/16-108.10)

Sec. 16-108.10. Energy low-income and support program. Beginning in 2017, without obtaining any approvals from the Commission or any other agency, regardless of whether any such approval would otherwise be required, a participating utility that is not a combination utility, as defined by Section 16-108.5 of this Act, shall contribute $10,000,000 per year for 5 years to the energy low-income and support program, which is intended to fund customer assistance programs with the primary purpose being avoidance of imminent disconnection and reconnecting customers who have been disconnected for non-payment. Such programs may include:

(1) a residential hardship program that may partner with community-based organizations, including senior citizen organizations, and provides grants to low-income residential customers, including low-income senior citizens, who demonstrate a hardship;

(2) a program that provides grants and other bill payment concessions to disabled veterans who demonstrate a hardship and members of the armed services or reserve forces of the United States or members of the Illinois National Guard who are on active duty under an executive order of the President of the United States, an act of the Congress of the United States, or an order of the Governor and who demonstrate a hardship;

(3) a budget assistance program that provides tools and education to low-income senior citizens to assist them with obtaining information regarding energy usage and effective means of managing energy costs;

(4) a non-residential special hardship program that provides grants to non-residential customers, such as small businesses and non-profit organizations, that demonstrate a hardship, including those providing services to senior citizen and low-income customers; and

(5) a performance-based assistance program that provides grants to encourage residential customers to make on-time payments by matching a portion of the customer's payments or providing credits towards arrearages.

The payments made by a participating utility under this Section shall not be a recoverable expense. A participating utility may elect to fund either new or existing customer assistance programs, including, but not limited to, those that are administered by the utility.

Programs that use funds that are provided by an electric utility to reduce utility bills may be implemented through tariffs that are filed with and reviewed by the Commission. If a utility elects to file tariffs with the Commission to implement all or a portion of the programs, those tariffs shall, regardless of the date actually filed, be deemed accepted and approved and shall become effective on the first business day after they are filed. The electric utilities whose customers benefit from the funds that are disbursed as contemplated in this Section shall file annual reports documenting the disbursement of those funds with the Commission. The Commission may audit disbursement of the funds to ensure they were disbursed consistently with this Section.

If the Commission finds that a participating utility is no longer eligible to update the performance-based formula rate tariff under subsection (d) of Section 16-108.5 of this Act or the performance-based formula rate is otherwise terminated, then the participating utility's obligations under this Section shall immediately terminate.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-108.11)

Sec. 16-108.11. Employment opportunities. To the extent feasible and consistent with State and federal law, the procurement of contracted labor, materials, and supplies by electric utilities in connection with the offering of delivery services under Article XVI of this Act should provide employment opportunities for all segments of the population and workforce, including minority-owned and female-owned business enterprises, and shall not, consistent with State and federal law, discriminate based on race or socioeconomic status.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-108.12)

Sec. 16-108.12. Utility job training program.

(a) An electric utility that serves more than 3,000,000 customers in the State shall spend $10,000,000 per year in 2017, 2021, and 2025 to fund the programs described in this Section.

(1) The utility shall fund a solar training pipeline program in the amount of $3,000,000. The utility may administer the program or contract with another entity to administer the program. The program shall be designed to establish a solar installer training pipeline for projects authorized under Section 1-56 of the Illinois Power Agency Act and to establish a pool of trained installers who will be able to install solar projects authorized under subsection (c) of Section 1-75 of the Illinois Power Agency Act and otherwise. The program may include single event training programs. The program described in this paragraph (1) shall be designed to ensure that entities that offer training are located in, and trainees are recruited from, the same communities that the program aims to serve and that the program provides trainees with the opportunity to obtain real-world experience. The program described in this paragraph (1) shall also be designed to assist trainees so that they can obtain applicable certifications or participate in an apprenticeship program. The utility or administrator shall include funding for programs that provide training to individuals who are or were foster children or that target persons with a record who are transitioning with job training and job placement programs. The program shall include an incentive to facilitate an increase of hiring of qualified persons who are or were foster children and persons with a record. It is a goal of the program described in this paragraph (1) that at least 50% of the trainees in this program come from within environmental justice communities and that 2,000 jobs are created for persons who are or were foster children and persons with a record.

(2) The utility shall fund a craft apprenticeship program in the amount of $3,000,000. The program shall be an accredited or otherwise recognized apprenticeship program over a period not to exceed 4 years, for particular crafts, trades, or skills in the electric industry that may, but need not, be related to solar installation.

(3) The utility shall fund multi-cultural jobs programs in the amount of $4,000,000. The funding shall be allocated in the applicable year to individual programs as set forth in subparagraphs (A) through (F) of this paragraph (3) and may, but need not, be related to solar installation, over a period not to exceed 4 years, by diversity-focused community organizations that have a record of successfully delivering job training.

(A) $1,000,000 to a community-based civil rights and human services not-for-profit organization that provides economic development, human capital, and education program services.

(B) $500,000 to a not-for-profit organization that is also an education institution that offers training programs approved by the Illinois State Board of Education and United States Department of Education with the goal of providing workforce initiatives leading to economic independence.

(C) $500,000 to a not-for-profit organization dedicated to developing the educational and leadership capacity of minority youth through the operation of schools, youth leadership clubs and youth development centers.

(D) $1,000,000 to a not-for-profit organization dedicated to providing equal access to opportunities in the construction industry that offer training programs that include Occupational Safety and Health Administration 10 and 30 certifications, Environmental Protection Agency Renovation, Repair and Painting Certification and Leadership in Energy and Environmental Design Accredited Green Associate Exam preparation courses.

(E) $500,000 to a non-profit organization that has a proven record of successfully implementing utility industry training programs, with expertise in creating programs that strengthen the economics of communities including technical training workshops and economic development through community and financial partners.

(F) $500,000 to a nonprofit organization that provides family services, housing education, job and career education opportunities that has successfully partnered with the utility on electric industry job training.

For the purposes of this Section, "person with a record" means any person who (1) has been convicted of a crime in this State or of an offense in any other jurisdiction, not including an offense or attempted offense that would subject a person to registration under the Sex Offender Registration Act; (2) has a record of an arrest or an arrest that did not result in conviction for any crime in this State or of an offense in any other jurisdiction; or (3) has a juvenile delinquency adjudication.

(b) Within 60 days after the effective date of this amendatory Act of the 99th General Assembly, an electric utility that serves more than 3,000,000 customers in the State shall file with the Commission a plan to implement this Section. Within 60 days after the plan is filed, the Commission shall enter an order approving the plan if it is consistent with this Section or, if the plan is not consistent with this Section, the Commission shall explain the deficiencies, after which time the utility shall file a new plan. The utility shall use the funds described in subparagraph (O) of paragraph (1) of subsection (c) of Section 1-75 of the Illinois Power Agency Act to pay for the Commission approved programs under this Section.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-108.15)

Sec. 16-108.15. Rate impacts.

(a) Each electric utility that serves more than 500,000 retail customers in the State shall file with the Commission the reports required by this Section, which shall identify the actual and projected average monthly increases in residential retail customers' electric bills due to future energy investment costs for the applicable period or periods.

(b) The average monthly increase calculation shall be comprised of the following components:

(1) Beginning with the 2017 calendar year, the average monthly amount paid by residential retail customers, expressed on a cents-per-kilowatthour basis, to recover future energy investment costs, which include the charges to recover the costs incurred by the utility under the following provisions:

(A) Sections 8-103, Section 8-103B, and 16-111.5B of this Act, as applicable, and as such costs may be recovered under Sections 8-103, 8-103B, 16-111.5B or Section 16-108.5 of this Act;

(B) subsection (d-5) of Section 1-75 of the Illinois Power Agency Act, as such costs may be recovered under subsection (k) of Section 16-108 of this Act; and

(C) Section 16-107.6 of this Act.

Beginning with the 2018 calendar year, each of the average monthly charges calculated in subparagraphs (A) through (C) of this paragraph (1) shall be equal to the average of each such charge applied over a period that commences with the calendar year ending December 31, 2017 and ends with the most recently completed calendar year prior to the calculation or calculations required by this Section.

(2) The sum of the following:

(A) net energy savings to residential retail customers that are attributable to the implementation of voltage optimization measures under Section 8-103B of this Act, expressed on a cents-per-kilowatthour basis, which are estimated energy and capacity benefits for residential retail customers minus the measure costs recovered from those customers, divided by the total number of residential retail customers, which quotient shall be divided by the months in the relevant period; notwithstanding this subparagraph (A), a utility may elect not to include an estimate of net energy savings as described in this subparagraph (A), in which case the value under this subparagraph (A) shall be zero; and

(B) for an electric utility that serves more than 3,000,000 retail customers in the State, the benefits of the programs described in Section 16-108.10 of this Act, which are $0.00030 per kilowatthour for the 2017, 2018, 2019, 2020, and 2021 calendar years.

Beginning with the 2018 calendar year, each of the values identified in subparagraphs (A) and (B) of this paragraph (2) shall be equal to the average of each such value during a period that commences with the calendar year ending December 31, 2017 and ends with the most recently completed calendar year prior to the calculation or calculations required by this Section.

(3) For an electric utility that serves more than 3,000,000 retail customers in the State, the residential retail customer energy efficiency charges shall be $2.33 per month for the 2017 calendar year, provided that such charge shall be increased by 4% per year thereafter; for an electric utility that serves more than 500,000 but less than 3,000,000 retail customers in the State, the residential retail customer energy efficiency charges shall be $3.94 per month for the 2017 calendar year, provided that such charge shall be increased by 4% per year thereafter. Beginning with the 2018 calendar year, this charge shall be equal to the average of the charges applied over a period that commences with the calendar year ending December 31, 2017 and ends with the most recently completed calendar year prior to the calculation or calculations required by this Section.

(c)(1) No later than June 30, 2017, an electric utility subject to this Section shall submit a report to the Commission that sets forth the utility's rolling 10-year projection of the values of each of the components described in paragraphs (1) through (3) of subsection (b) of this Section. No later than February 15, 2018 and every February 15 thereafter until February 15, 2031, each utility shall submit a report to the Commission that identifies the value of the actual charges applied during the immediately preceding calendar year and updates its rolling 10-year projection based on such actual charges provided that, beginning with the February 15, 2021 report and for each report thereafter, the period of time covered by such projection shall not extend beyond December 31, 2030. Each report submitted under this subsection (c) shall calculate the actual average monthly increase in residential retail customers' electric bills due to future energy investment costs during the immediately preceding calendar year and shall also calculate the projected average monthly increase in residential retail customers' electric bills due to such costs over the rolling 10-year period. Such calculations shall be performed by subtracting the sum of paragraph (2) of subsection (b) of this Section from the sum of paragraph (1) of such subsection (b), multiplying such difference by, as applicable, the actual or forecasted average monthly kilowatthour consumption for the residential retail customer class for the applicable period, and subtracting from such product the applicable value identified under paragraph (3) of such subsection (b).

If the actual or projected average monthly increase for residential retail customers of electric utility that serves more than 3 million retail customers in the State exceeds $0.25, or the actual or projected average monthly increase for residential retail customers of an electric utility that serves more than 500,000 but less than 3 million retail customers in the State exceeds $0.35, then the applicable utility shall comply with the provisions of paragraphs (2) through (4) of this subsection (c), as applicable.

(2) If the projected average monthly increase for residential retail customers during a calendar year exceeds the applicable limitation set forth in paragraph (1) of this subsection (c), then the utility shall comply with the following provisions, as applicable:

(A) If an exceedance is projected during the first four calendar year of the rolling 10-year projection, then the utility shall include in its report submitted under paragraph (1) of this subsection (c) the utility's proposal or proposals to decrease the future energy investment costs described in paragraph (1) of subsection (b) of this Section to ensure that the limitation set forth in such paragraph (1) is not exceeded. The Commission shall, after notice and hearing, enter an order directing the utility to implement one or more proposals, as such proposals may be modified by the Commission. The Commission shall have the authority under this subparagraph (A) to approve modifications to the contracts executed under subsection (d-5) of Section 1-75 of the Illinois Power Agency Act. If the Commission approves modifications to such contracts, then the supplier shall have the option of accepting the modifications or terminating the modified contract or contracts, subject to the termination requirements and notice provisions set forth in item (i) of subparagraph (B) of paragraph (4) of this Section.

(B) If an exceedance is projected during any calendar year during the last 6 years of the 10-year projection, then the utility shall demonstrate in its report submitted under paragraph (1) of this subsection (c) how the utility will reduce the future energy investment costs described in paragraph (1) of subsection (b) of this Section to ensure that the limitation set forth in such paragraph (1) is not exceeded.

(3) If the actual average monthly increase for residential retail customers during a calendar year exceeded the limitation set forth in paragraph (1) of this subsection (c), then the utility shall prepare and file with the Commission, at the time it submits its report under paragraph (1) of this subsection (c), a corrective action plan that identifies how the utility will immediately reduce expenditures so that the utility will be in compliance with such limitation beginning on January 1 of the next calendar year. The Commission shall initiate an investigation to determine the factors that contributed to the actual average monthly increase exceeding such limitation for the applicable calendar year, and shall, after notice and hearing, enter an order approving, or approving with modification, the utility's corrective action plan within 120 days after the utility files such plan. The Commission shall also submit a report to the General Assembly no later than 30 days after it enters such order, and the report shall explain the results of the Commission's investigation and findings and conclusions of its order.

(4) If the actual average monthly increase for residential retail customers during a calendar year exceeds the limitation set forth in paragraph (1) of this subsection (c) for two consecutive years, then the utility shall indicate in its report filed under paragraph (1) of this subsection (c) whether the utility will proceed with or terminate the future energy investments described and authorized under subsection (d-5) of the Illinois Power Agency Act and Sections 8-103B and 16-107.6 of this Act. The utility shall be subject to the requirements of subparagraph (A) or (B) of this paragraph (4), as applicable.

(A) If the utility indicates that it will proceed with the future energy investments, then it shall be subject to the corrective action plan requirements set forth in paragraph (3) of this subsection (c). In addition, the utility must commit to apply a credit to residential retail customers' bills if the actual average monthly increase for such customers exceeds the limitation set forth in paragraph (1) of this subsection (c) for the year in which the utility files its corrective action plan, which credit shall be in an amount that equals the portion by which the increase exceeds such limitation. The Commission shall initiate an investigation to determine the factors that contributed to the actual average monthly increase exceeding such limitation for the applicable calendar year, including an analysis of the factors contributing to the limitation being exceeded for two consecutive years, and shall, after notice and hearing, enter an order approving, or approving with modification, the utility's corrective action plan within 120 days after the utility files such plan. The Commission shall also submit a supplemental report to the General Assembly no later than 30 days after it enters such order, and the report shall explain the results of the Commission's investigation and findings and conclusions of its order.

(B) If the utility indicates that it will terminate future energy investments, then the Commission shall, notwithstanding anything to the contrary:

(i) Order the utility to terminate the contract or contracts executed under subsection (d-5) of Section 1-75 of the Illinois Power Agency Act, pursuant to the contract termination provisions set forth in such subsection (d-5), provided that notice of such termination must be made at least 3 years and 75 days prior to the effective date of such termination. In the event that only a portion of the contracts executed under such subsection (d-5) are terminated for a particular zero emission facility, then the zero emission facility may elect to terminate all of the contracts executed for that facility under such subsection (d-5).

(ii) Within 30 days after the utility submits its report indicates that it will terminate future energy investments, initiate a proceeding to approve the process for terminating future expenditures under Section 16-107.6 of the Public Utilities Act. The Commission shall, after notice and hearing, enter its order approving such process no later than 120 days after initiating such proceeding.

(iii) Within 30 days after the utility submits its report indicates that it will terminate future energy investments, initiate a proceeding under Section 8-103B of this Act to reduce the cumulative persisting annual savings goals previously approved by the Commission under such Section to ensure just and reasonable rates. The Commission shall, after notice and hearing, enter its order approving such goal reductions no later than 120 days after initiating such proceeding.

Notwithstanding the termination of future energy investments pursuant to this subparagraph (B), the utility shall be permitted to continue to recover the costs of such investments that were incurred prior to such termination, including but not limited to all costs that are recovered through regulatory assets created under Sections 8-103B and 16-107.6 of this Act. Nothing in this Section shall limit the utility's ability to fully recover such costs. The utility shall also be permitted to continue to recover the costs of all payments made under contracts executed under subsection (d-5) until the effective date of the contract's termination.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-108.16)

Sec. 16-108.16. Commercial Rate Impacts.

(a) Each electric utility that serves more than 500,000 retail customers in the State shall file with the Commission the reports required by this Section, which shall identify the annual average increases due to future energy investment costs for the applicable period or periods in electric bills to commercial and industrial retail customers. For purposes of this Section, "commercial and industrial retail customers" means non-residential retail customers other than those customers who are exempt from subsections (a) through (j) of Section 8-103B of this Act under subsection (l) of Section 8-103B.

(b) The increase determination required by subsection (a) of this Section shall be based on a calculation comprised of the following components:

(1) Beginning with the 2017 calendar year, the average annual amount paid by commercial and industrial retail customers, expressed on a cents-per-kilowatthour basis, to recover future energy investment costs, which include the charges to recover the costs incurred by the utility under the following provisions:

(A) Sections 8-103, Section 8-103B, and 16-111.5B of this Act, as applicable, and as such costs may be recovered under Sections 8-103, 8-103B, 16-111.5B or Section 16-108.5 of this Act;

(B) subsection (d-5) of Section 1-75 of the Illinois Power Agency Act, as such costs may be recovered under subsection (k) of Section 16-108 of this Act; and

(C) Section 16-107.6 of this Act.

Beginning with the 2018 calendar year, each of the average annual charges calculated in subparagraphs (A) through (C) of this paragraph (1) shall be equal to the average of each such charge applied over a period that commences with the calendar year ending December 31, 2017 and ends with the most recently completed calendar year prior to the calculation or calculations required by this Section.

(2) The sum of the following:

(A) annual net energy savings to commercial and industrial retail customers that are attributable to the implementation of voltage optimization measures under Section 8-103B of this Act, expressed on a cents-per-kilowatthour basis, which are estimated energy and capacity benefits for commercial and industrial retail customers minus the measure costs recovered from those customers, divided by the average annual kilowatt-hour consumption of commercial and industrial retail customers; notwithstanding this subparagraph (A), a utility may elect not to include an estimate of net energy savings as described in this subparagraph (A), in which case the value under this subparagraph (A) shall be zero;

(B) the average annual cents-per-kilowatthour charge applied under Section 8-103 of this Act to commercial and industrial retail customers during calendar year 2016 to recover the costs authorized by such Section; and

(C) incremental energy efficiency savings, which shall be calculated by subtracting the value determined in item (ii) of this subparagraph (C) from the value determined in item (i) of this subparagraph and dividing the difference by the value identified in item (iii) of this subparagraph:

(i) Total value, in dollars, of the cumulative persisting annual saving achieved from the installation or implementation of all energy efficiency measures for commercial and industrial retail customers under Sections 8-103, 8-103B and 16-111.5 of this Act, net of the cumulative annual percentage savings in kilowatt-hours, if any, calculated under subparagraph (A) of this paragraph (2).

(ii) 2016 value, which shall equal the value calculated under item (i) of this subparagraph (C) multiplied by the quotient of (aa) the cumulative persisting annual savings, in kilowatt-hours, achieved from the installation or implementation of all energy efficiency measures for commercial and industrial retail customers under Sections 8-103, 8-103B and 16-111.5B of this Act as of December 31, 2016, divided by (bb) the cumulative persisting annual savings, in kilowatt-hours, from the installation or implementation of all energy efficiency measures for commercial and industrial retail customers under Sections 8-103, 8-103B and 16-111.5 of this Act, net of the cumulative annual percentage savings in kilowatt-hours, if any, calculated under subparagraph (A) of this paragraph (2).

(iii) The average annual kilowatt-hour consumption of those commercial and industrial retail customers that installed or implemented energy efficiency measures under energy efficiency programs or plans approved pursuant to Sections 8-103, 8-103B or 16-111.5B of this Act.

Beginning with the 2018 calendar year, each of the values identified in subparagraphs (A) and (C) of this paragraph (2) shall be equal to the average of each such value during a period that commences with the calendar year ending December 31, 2017 and ends with the most recently completed calendar year prior to the calculation or calculations required by this Section.

For purposes of this Section, cumulative persisting annual savings shall have the meaning set forth in Section 8-103B of this Act, and energy efficiency measures shall have the meaning set forth in Section 1-10 of the Illinois Power Agency Act.

(c)(1) No later than June 30, 2017, and every June 30 thereafter until June 30, 2027, an electric utility subject to this Section shall submit a report to the Commission that sets forth the utility's 10-year projection of the values of each of the components described in paragraphs (1) and (2) of subsection (b) of this Section. Each utility's report to the Commission shall identify the result of the computation performed under this Section for the immediately preceding calendar year and update its 10-year projection. Such calculations shall be performed by subtracting the sum of paragraph (2) of subsection (b) of this Section from the sum of paragraph (1) of such subsection (b).

In the event that the actual or projected average annual increase for commercial and industrial retail customers exceeds 1.3% of 8.90 cents-per-kilowatthour, which is the average amount paid per kilowatt-hour for electric service during the year ending December 31, 2015 by Illinois commercial retail customers, as reported to the Edison Electric Institute, then the applicable utility shall comply with the provisions of paragraphs (2) through (4) of this subsection (c), as applicable.

(2) In the event that the projected average annual increase for commercial and industrial retail customers during a calendar year exceeds the applicable limitation set forth in paragraph (1) of this subsection (c), then the utility shall comply with the following provisions, as applicable:

(A) If an exceedance is projected during the first four calendar years of the 10-year projection, then the utility shall include in its report submitted under paragraph (1) of this subsection (c) the utility's proposal or proposals to decrease the future energy investment costs described in paragraph (1) of subsection (b) of this Section to ensure that the limitation set forth in such paragraph (1) is not exceeded. The Commission shall, after notice and hearing, enter an order directing the utility to implement one or more proposals, as such proposals may be modified by the Commission. The Commission shall have the authority under this subparagraph (A) to approve modifications to the contracts executed under subsection (d-5) of Section 1-75 of the Illinois Power Agency Act. If the Commission approves modifications to such contracts that are in an amount that reduces the quantities to be procured under such contracts by more than 7%, then the supplier shall have the option of accepting the modifications or terminating the modified contract or contracts, subject to the termination requirements and notice provisions set forth in item (i) of subparagraph (B) of paragraph (4) of this Section.

(B) If an exceedance is projected during any calendar year during the last 6 years of the 10-year projection, then the utility shall demonstrate in its report submitted under paragraph (1) of this subsection (c) how the utility will reduce the future energy investment costs described in paragraph (1) of subsection (b) of this Section to ensure that the limitation set forth in such paragraph (1) is not exceeded.

(3) If the actual average annual increase for commercial and industrial retail customers during a calendar year exceeded the limitation set forth in paragraph (1) of this subsection (c), then the utility shall prepare and file with the Commission, at the time it submits its report under paragraph (1) of this subsection (c), a corrective action plan. The Commission shall initiate an investigation to determine the factors that contributed to the actual average annual increase exceeding such limitation for the applicable calendar year, and shall, after notice and hearing, enter an order approving, or approving with modification, the utility's corrective action plan within 120 days after the utility files such plan. The Commission shall also submit a report to the General Assembly no later than 30 days after it enters such order, and the report shall explain the results of the Commission's investigation and findings and conclusions of its order.

(4) If the actual average annual increase for commercial and industrial retail customers during a calendar year exceeds the limitation set forth in paragraph (1) of this subsection (c) for two consecutive years, then the utility shall indicate in its report filed under paragraph (1) of this subsection (c) whether the utility will proceed with or terminate the future energy investments described and authorized under subsection (d-5) of the Illinois Power Agency Act and Sections 8-103B and 16-107.6 of this Act. The utility's election shall be subject to the requirements of subparagraph (A) or (B) of this paragraph (4), as applicable.

(A) If the utility elects to proceed with the future energy investments, then it shall be subject to the corrective action plan requirements set forth in paragraph (3) of this subsection (c). In addition, the utility must commit to apply a credit to commercial and industrial retail customers' bills if the actual average annual increase for such customers exceeds the limitation set forth in paragraph (1) of this subsection (c) for the year in which the utility files its corrective action plan, which credit shall be in an amount that equals the portion by which the increase exceeds such limitation. The Commission shall initiate an investigation to determine the factors that contributed to the actual average annual increase exceeding such limitation for the applicable calendar year, including an analysis of the factors contributing to the limitation being exceeded for two consecutive years, and shall, after notice and hearing, enter an order approving, or approving with modification, the utility's corrective action plan within 120 days after the utility files such plan. The Commission shall also submit a supplemental report to the General Assembly no later than 30 days after it enters such order, and the report shall explain the results of the Commission's investigation and findings and conclusions of its order.

(B) If the utility elects to terminate future energy investments, then the Commission shall, notwithstanding anything to the contrary:

(i) Order the utility to terminate the contract or contracts executed under subsection (d-5) of Section 1-75 of the Illinois Power Agency Act, pursuant to the contract termination provisions set forth in such subsection (d-5), provided that notice of such termination must be made at least 3 years and 75 days prior to the effective date of such termination. In the event that only a portion of the contracts executed under such subsection (d-5) are terminated for a particular zero emission facility, then the zero emission facility may elect to terminate all of the contracts executed for that facility under such subsection (d-5).

(ii) Within 30 days of the utility's report identifying its election to terminate future energy investments, initiate a proceeding to approve the process for terminating future expenditures under Sections 16-107.6 of the Public Utilities Act. The Commission shall, after notice and hearing, enter its order approving such process no later than 120 days after initiating such proceeding.

(iii) Within 30 days of the utility's report identifying its election to terminate future energy investments, initiate a proceeding under Section 8-103B of this Act to reduce the cumulative persisting annual savings goals previously approved by the Commission under such Section to ensure just and reasonable rates. The Commission shall, after notice and hearing, enter its order approving such goal reductions no later than 120 days after initiating such proceeding.

Notwithstanding the termination of future energy investments pursuant to this subparagraph (B), the utility shall be permitted to continue to recover the costs of such investments that were incurred prior to such termination, including but not limited to all costs that are recovered through regulatory assets created under Sections 8-103B and 16-107.6 of this Act. Nothing in this Section shall limit the utility's ability to fully recover such costs. The utility shall also be permitted to continue to recover the costs of all payments made under contracts executed under subsection (d-5) until the effective date of the contract's termination.

(5) Notwithstanding anything to the contrary, if, under this Section or subsection (m) of Section 16-108 of this Act, modifications to the contracts executed under subsection (d-5) of Section 1-75 of the Illinois Power Agency Act are, in total, in an amount that reduces the quantities to procured under such contracts by more than 10%, then the supplier shall have the option of accepting the modifications or terminating the modified contract or contracts, subject to the termination requirements and notice provisions set forth in item (i) of subparagraph (B) of paragraph (4) of this Section.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-108.18)

Sec. 16-108.18. Performance-based ratemaking.

(a) The General Assembly finds:

(1) That improving the alignment of utility customer and company interests is critical to ensuring equity, rapid growth of distributed energy resources, electric vehicles, and other new technologies that substantially change the makeup of the grid and protect Illinois residents and businesses from potential economic and environmental harm from the State's energy systems.

(2) There is urgency around addressing increasing threats from climate change and assisting communities that have borne disproportionate impacts from climate change, including air pollution, greenhouse gas emissions, and energy burdens. Addressing this problem requires changes to the business model under which utilities in Illinois have traditionally functioned.

(3) Providing targeted incentives to support change through a new performance-based structure to enhance ratemaking is intended to enable alignment of utility, customer, community, and environmental goals.

(4) Though Illinois has taken some measures to move utilities to performance-based ratemaking through the establishment of performance incentives and a performance-based formula rate under the Energy Infrastructure Modernization Act, these measures have not been sufficiently transformative in urgently moving electric utilities toward the State's ambitious energy policy goals: protecting a healthy environment and climate, improving public health, and creating quality jobs and economic opportunities, including wealth building, especially in economically disadvantaged communities and communities of color.

(5) These measures were not developed through a process to understand first what performance measures and penalties would help drive the sought-after behavior by the utilities.

(6) While the General Assembly has not made a finding that the spending related to the Energy Infrastructure and Modernization Act and its performance metrics was not reasonable, it is important to address concerns that these measures may have resulted in excess utility spending and guaranteed profits without meaningful improvements in customer experience, rate affordability, or equity.

(7) Discussions of performance incentive mechanisms must always take into account the affordability of customer rates and bills for all customers, including low-income customers.

(8) The General Assembly therefore directs the Illinois Commerce Commission to complete a transition that includes a comprehensive performance-based regulation framework for electric utilities serving more than 500,000 customers. The breadth of this framework should revise existing utility regulations to position Illinois electric utilities to effectively and efficiently achieve current and anticipated future energy needs of this State, while ensuring affordability for consumers.

(b) As used in this Section:

"Commission" means the Illinois Commerce Commission.

"Demand response" means measures that decrease peak electricity demand or shift demand from peak to off-peak periods.

"Distributed energy resources" or "DER" means a wide range of technologies that are connected to the grid including those that are located on the customer side of the customer's electric meter and can provide value to the distribution system, including, but not limited to, distributed generation, energy storage, electric vehicles, and demand response technologies.

"Economically disadvantaged communities" means areas of one or more census tracts where average household income does not exceed 80% of area median income.

"Environmental justice communities" means the definition of that term as used and as may be updated in the long-term renewable resources procurement plan by the Illinois Power Agency and its Program Administrator in the Illinois Solar for All Program.

"Equity investment eligible community" means the geographic areas throughout Illinois which would most benefit from equitable investments by the State designed to combat discrimination. Specifically, the equity investment eligible communities shall be defined as the following areas:

(1) R3 Areas as established pursuant to Section 10-40 of the Cannabis Regulation and Tax Act, where residents have historically been excluded from economic opportunities, including opportunities in the energy sector; and

(2) Environmental justice communities, as defined by the Illinois Power Agency pursuant to the Illinois Power Agency Act, where residents have historically been subject to disproportionate burdens of pollution, including pollution from the energy sector.

"Performance incentive mechanism" means an instrument by which utility performance is incentivized, which could include a monetary performance incentive.

"Performance metric" means a manner of measurement for a particular utility activity.

(c) Through coordinated, comprehensive system planning, ratemaking, and performance incentives, the performance-based ratemaking framework should be designed to accomplish the following objectives:

(1) maintain and improve service reliability and safety, including and particularly in environmental justice, low-income and equity investment eligible communities;

(2) decarbonize utility systems at a pace that meets or exceeds State climate goals, while also ensuring the affordability of rates for all customers, including low-income customers;

(3) direct electric utilities to make cost-effective investments that support achievement of Illinois' clean energy policies, including, at a minimum, investments designed to integrate distributed energy resources, comply with critical infrastructure protection standards, plans, and industry best practices, and support and take advantage of potential benefits from the electric vehicle charging and other electrification, while mitigating the impacts;

(4) choose cost-effective assets and services, whether utility-supplied or through third-party contracting, considering both economic and environmental costs and the effects on utility rates, to deliver high-quality service to customers at least cost;

(5) maintain the affordability of electric delivery services for all customers, including low-income customers;

(6) maintain and grow a diverse workforce, diverse supplier procurement base and, for relevant programs, diverse approved-vendor pools, including increased opportunities for minority-owned, female-owned, veteran-owned, and disability-owned business enterprises;

(7) improve customer service performance and engagement;

(8) address the particular burdens faced by consumers in environmental justice and equity investment eligible communities, including shareholder, consumer, and publicly funded bill payment assistance and credit and collection policies, and ensure equitable disconnections, late fees, or arrearages as a result of utility credit and collection practices, which may include consideration of impact by zip code; and

(9) implement or otherwise enhance current supplier diversity programs to increase diverse contractor participation in professional services, subcontracting, and prime contracting opportunities with programs that address barriers to access. Supplier diversity programs shall address specific barriers related to RFP and contract access, access to capital, information technology and cyber security access and costs, administrative burdens, and quality control with specific metrics, outcomes, and demographic data reported.

(d) Multi-Year Rate Plan.

(1) If an electric utility had a performance-based formula rate in effect under Section 16-108.5 as of December 31, 2020, then the utility may file a petition proposing tariffs implementing a 4-year Multi-Year Rate Plan as provided in this Section no later than, January 20, 2023, for delivery service rates to be effective for the billing periods January 1, 2024 through December 31, 2027. The Commission shall issue an order approving or approving as modified the utility's plan no later than December 20, 2023. The term "Multi-Year Rate Plan" refers to a plan establishing the base rates the utility shall charge for each delivery year of the 4-year period to be covered by the plan, which shall be subject to modification only as expressly allowed in this Section.

(2) A utility proposing a Multi-Year Rate Plan shall provide a 4-year investment plan and a description of the utility's major planned investments, including, at a minimum, all investments of $2,000,000 or greater over the plan period for an electric utility that serves more than 3,000,000 retail customers in the State or $500,000 for an electric utility that serves less than 3,000,000 retail customers in the State but more than 500,000 retail customers in the State. The 4-year investment plan must be consistent with the Multi-Year Integrated Grid Plan described in Section 16-105.17 of this Act. The investment plan shall provide sufficiently detailed information, as required by the Commission, including, at a minimum, a description of each investment, the location of the investment, and an explanation of the need for and benefit of such an investment to the extent known.

(3) The Multi-Year Rate Plan shall be implemented through a tariff filed with the Commission consistent with the provisions of this paragraph (3) that shall apply to all delivery service customers. The Commission shall initiate and conduct an investigation of the tariff in a manner consistent with the provisions of this paragraph (3) and the provisions of Article IX of this Act, to the extent they do not conflict with this paragraph (3). The Multi-Year Rate Plan approved by the Commission shall do the following:

(A) Provide for the recovery of the utility's forecasted rate base, based on the 4-year investment plan and the utility's Integrated Grid Plan. The forecasted rate base must include the utility's planned capital investments, with rates based on average annual plant investment, and investment-related costs, including income tax impacts, depreciation, and ratemaking adjustments and costs that are prudently incurred and reasonable in amount consistent with Commission practice and law. The process used to develop the forecasts must be iterative, rigorous, and lead to forecasts that reasonably represent the utility's investments during the forecasted period and ensure that the investments are projected to be used and useful during the annual investment period and least cost, consistent with the provisions of Articles VIII and IX of this Act.

(B) The cost of equity shall be approved by the Commission consistent with Commission practice and law.

(C) The revenue requirement shall reflect the utility's actual capital structure for the applicable calendar year. A year-end capital structure that includes a common equity ratio of up to and including 50% of the total capital structure shall be deemed prudent and reasonable. A higher common equity ratio must be specifically approved by the Commission.

(E) Provide for recovery of prudent and reasonable projected operating expenses, giving effect to ratemaking adjustments, consistent with Commission practice and law under Article IX of this Act. Operating expenses for years after the first year of the Multi-Year Rate Plan may be estimated by the use of known and measurable changes, expense reductions associated with planned capital investments as appropriate, and reasonable and appropriate escalators, indices, or other metrics.

(F) Amortize the amount of unprotected property-related excess accumulated deferred income taxes in rates as of January 1, 2023 over a period ending December 31, 2027, unless otherwise required to amortize the excess deferred income tax pursuant to Section 16-108.21 of this Act.

(G) Allow recovery of incentive compensation expense that is based on the achievement of operational metrics, including metrics related to budget controls, outage duration and frequency, safety, customer service, efficiency and productivity, environmental compliance and attainment of affordability and environmental goals, and other goals and metrics approved by the Commission. Incentive compensation expense that is based on net income or an affiliate's earnings per share shall not be recoverable.

(H) To the maximum extent practicable, align the 4-year investment plan and annual capital budgets with the electric utility's Multi-Year Integrated Grid Plan.

(4) The Commission shall establish annual rates for each year of the Multi-Year Rate Plan that accurately reflect and are based only upon the utility's reasonable and prudent costs of service over the term of the plan, including the effect of all ratemaking adjustments consistent with Commission practice and law as determined by the Commission, provided that the costs are not being recovered elsewhere in rates. Tariff riders authorized by the Commission may continue outside of a plan authorized under this Section to the extent such costs are not recovered elsewhere in rates. For the first multi-year rate plan, the burden of proof shall be on the electric utility to establish the prudence of investments and expenditures and to establish that such investments consistent with and reasonably necessary to meet the requirements of the utility's first approved Multi-Year Integrated Grid Plan described in Section 16-105.17 of this Act. For subsequent Multi-Year Rate Plans, the burden of proof shall be on the electric utility to establish the prudence of investments and expenditures and to establish that such investments are consistent with and reasonably necessary to meet the requirements of the utility's most recently approved Multi-Year Integrated Grid Plan described in Section 16-105.17 of this Act. The sole fact that a cost differs from that incurred in a prior period or that an investment is different from that described in the Multi-Year Integrated Grid Plan shall not imply the imprudence or unreasonableness of that cost or investment. The sole fact that an investment is the same or similar to that described in the Multi-Year Integrated Grid Plan shall not imply prudence and reasonableness of that investment.

(5) To facilitate public transparency, all materials, data, testimony, and schedules shall be provided to the Commission in an editable, machine-readable electronic format including .doc, .docx, .xls, .xlsx, and similar file formats, but not including .pdf or .exif. Should utilities designate any materials confidential, they shall have an affirmative duty to explain why the particular information is marked confidential. In determining prudence and reasonableness of rates, the Commission shall make its determination based upon the record, including each public comment filed or provided orally at open meetings consistent with the Commission's rules and practices.

(6) The Commission may, by order, establish terms, conditions, and procedures for submitting and approving a Multi-Year Rate Plan necessary to implement this Section and ensure that rates remain just and reasonable during the course of the plan, including terms and procedures for rate adjustment.

(7) An electric utility that files a tariff pursuant to paragraph (3) of this subsection (e) must submit a one-time $300,000 filing fee at the time the Chief Clerk of the Commission accepts the filing, which shall be a recoverable expense.

(8) An electric utility operating under a Multi-Year Rate Plan shall file a new Multi-Year Rate Plan at least 300 days prior to the end of the initial Multi-Year Rate Plan unless it elects to file a general rate case pursuant to paragraph (9), and every 4 years thereafter, with a rate-effective date of the proposed tariffs such that, after the Commission suspension period, the rates would take effect immediately at the close of the final year of the initial Multi-Year Rate Plan. In subsequent Multi-Year Rate Plans, as in the initial plans, utilities and stakeholders may propose additional metrics that achieve the outcomes described in paragraph (2) of subsection (f) of this Section.

(9) Election of Rate Case.

(A) On or before the date prescribed by subparagraph (B) of paragraph (9) of this Section, electric utilities that serve more than 500,000 retail customers in the State shall file either a general rate case under Section 9-201 of this Act, or a Multi-Year Rate Plan, as set forth in paragraph (1) of this subsection (d).

(B) Electric utilities described in subparagraph (A) of paragraph (9) of this Section shall file their initial general rate case or Multi-Year Rate Plan, as applicable, with the Commission no later than January 20, 2023.

(C) Notwithstanding which rate filing option an electric utility elects to file on the date prescribed by subparagraph (B) of paragraph (9) of this Section, the electric utility shall be subject to the Multi-year Integrated Plan filing requirements.

(D) Following its initial rate filing pursuant to paragraph (2), an electric utility subject to the requirements of this Section shall thereafter be permitted to elect a different rate filing option consistent with any filing intervals established for a general rate case or Multi-Year Rate Plan, as follows:

(i) An electric utility that initially elected to file a Multi-Year Rate Plan and thereafter elects to transition to a general rate case may do so upon completion of the 4-year Multi-Year Rate Plan by filing a general rate case at the same time that the utility would have filed its subsequent Multi-Year Rate Plan, as specified in paragraph (8) of this subsection (d). Notwithstanding this election, the annual adjustment of the final year of the Multi-Year Rate Plan shall proceed as specified in paragraph (6) of subsection (f).

(ii) An electric utility that initially elected to a file general rate case and thereafter elects to transition to a Multi-Year Rate Plan may do so only at the 4-year filing intervals identified by paragraph (8) of this subsection (d).

(10) The Commission shall approve tariffs establishing rate design for all delivery service customers unless the electric utility makes the election specified in Section 16-105.5, in which case the rate design shall be subject to the provisions of that Section.

(11) The Commission shall establish requirements for annual performance evaluation reports to be submitted annually for performance metrics. Such reports shall include, but not be limited to, a description of the utility's performance under each metric and an identification of any extraordinary events that adversely affected the utility's performance.

(12) For the first Multi-Year Rate Plan, the Commission shall consolidate its investigation with the proceeding under Section 16-105.17 to establish the Multi-Year Integrated Grid Plan no later than 45 days after plan filing.

(13) Where a rate change under a Multi-Year Rate Plan will result in a rate increase, an electric utility may propose a rate phase-in plan that the Commission shall approve with or without modification or deny in its final order approving the new delivery services rates. A proposed rate phase-in plan under this paragraph (13) must allow the new delivery services rates to be implemented in no more than 2 steps, as follows: in the first step, at least 50% of the approved rate increase must be reflected in rates, and, in the second step, 100% of the rate increase must be reflected in rates. The second step's rates must take effect no later than 12 months after the first step's rates were placed into effect. The portion of the approved rate increase not implemented in the first step shall be recorded on the electric utility's books as a regulatory asset, and shall accrue carrying costs to ensure that the utility does not recover more or less than it otherwise would because of the deferral. This portion shall be recovered, with such carrying costs at the weighted average cost of capital, through a surcharge applied to retail customer bills that (i) begins no later than 12 months after the date on which the second step's rates went into effect and (ii) is applied over a period not to exceed 24 months. Nothing in this paragraph is intended to limit the Commission's authority to mitigate the impact of rates caused by rate plans, or any other instance on a revenue-neutral basis; nor shall it mitigate a utility's ability to make proposals to mitigate the impact of rates. When a deferral, or similar method, is used to mitigate the impact of rates, the utility should be allowed to recover carrying costs.

(14) Notwithstanding the provisions of Section (13), the Commission may, on its own initiative, take revenue-neutral measures to relieve the impact of rate increases on customers. Such initiatives may be taken by the Commission in the first Multi-Year Rate Plan, subsequent multi-year plans, or in other instances described in this Act.

(15) Whenever during the pendency of a Multi-year Rate Plan, an electric utility subject to this Section becomes aware that, due to circumstances beyond its control, prudent operating practices will require the utility to make adjustments to the Multi-Year Rate Plan, the electric utility may file a petition with the Commission requesting modification of the approved annual revenue requirements included in the Multi-Year Rate Plan. The electric utility must support its request with evidence demonstrating why a modification is necessary, due to circumstances beyond the utility's control, to follow prudent operating practices and must set forth the changes to each annual revenue requirement to be approved, and the basis for any changes in anticipated operating expenses or capital investment levels. The utility shall affirmatively address the impact of the changes on the Multi-Year Integrated Grid Plan and Multi-Year Rate Plan originally submitted and approved by the Commission. Any interested party may file an objection to the changes proposed, or offer alternatives to the utility's proposal, as supported by testimony and evidence. After notice and hearing, the Commission shall issue a final order regarding the electric utility's request no later than 180 days after the filing of the petition.

(e) Performance incentive mechanisms.

(1) The electric industry is undergoing rapid transformation, including fundamental changes in how electricity is generated, procured, and delivered and how customers are choosing to participate in the supply and delivery of electricity to and from the electric grid. Building upon the State's goals to increase the procurement of electricity from renewable energy resources, including distributed generation and storage devices, the General Assembly finds that electric utilities should make cost-effective investments that support moving forward on Illinois' clean energy policies. It is therefore in the State's interest for the Commission to establish performance incentive mechanisms in order to better tie utility revenues to performance and customer benefits, accelerate progress on Illinois energy and other goals, ensure equity and affordability of rates for all customers, including low-income customers, and hold utilities publicly accountable.

(2) The Commission shall approve, based on the substantial evidence proffered in the proceeding initiated pursuant to this subsection performance metrics that, to the extent practicable and achievable by the electric utility, encourage cost-effective, equitable utility achievement of the outcomes described in this subsection (e) while ensuring no degradation in the significant performance improvement achieved through previously established performance metrics. For each electric utility, the Commission shall approve metrics designed to achieve incremental improvements over baseline performance values and targets, over a performance period of up to 10 years, and no less than 4 years.

(A) The Commission shall approve no more than 8 metrics, with at least one metric from each of the categories below, for each electric utility, from subparagraphs (i) through (vi) of this subsection (A). Upon a utility request, the Commission may approve the use of a specific, measurable, and achievable tracking metric described in paragraph (3) of subsection (e) as a performance metric pursuant to paragraph (2) of subsection (e).

(i) Metrics designed to ensure the utility maintains and improves the high standards of both overall and locational reliability and resiliency, and makes improvements in power quality, including and particularly in environmental justice and equity investment eligible communities.

(ii) Peak load reductions attributable to demand response programs.

(iii) Supplier diversity expansion, including diverse contractor participation in professional services, subcontracting, and prime contracting opportunities, development of programs that address the barriers to access, aligning demographics of contractors to the demographics in the utility's service territory, establish long-term mentoring relationships that develop and remove barriers to access for diverse and underserved contractors. The utilities shall provide solutions, resources, and tools to address complex barriers of entry related to costly and time-intensive cyber security requirements, increasingly complex information technology requirements, insurance barriers, service provider sign-up process barriers, administrative process barriers, and other barriers that inhibit access to RFPs and contracts. For programs with contracts over $1,000,000, winning bidders must demonstrate a subcontractor development or mentoring relationship with at least one of their diverse subcontracting partners for a core component of the scope of the project. The mentoring time and cost shall be taken into account in the creation of RFP and shall include a structured and measured plan by the prime contractor to increase the capabilities of the subcontractor in their proposed scope. The metric shall include reporting on all supplier diversity programs by goals, program results, demographics and geography, with separate reporting by category of minority-owned, female-owned, veteran-owned, and disability-owned business enterprise metrics. The report shall include resources and expenses committed to the programs and conversion rates of new diverse utility contractors.

(iv) Achieve affordable customer delivery service costs, with particular emphasis on keeping the bills of lower-income households, households in equity investment eligible communities, and household in environmental justice communities within a manageable portion of their income and adopting credit and collection policies that reduce disconnections for these households specifically and for customers overall to ensure equitable disconnections, late fees, or arrearages as a result of utility credit and collection practices, which may include consideration of impact by zip code.

(v) Metrics designed around the utility's timeliness to customer requests for interconnection in key milestone areas, such as: initial response, supplemental review, and system feasibility study; improved average service reliability index for those customers that have interconnected a distributed renewable energy generation device to the utility's distribution system and are lawfully taking service under an applicable tariff; offering a variety of affordable rate options, including demand response, time of use rates for delivery and supply, real-time pricing rates for supply; comprehensive and predictable net metering, and maximizing the benefits of grid modernization and clean energy for ratepayers; and improving customer access to utility system information according to consumer demand and interest.

(vi) Metrics designed to measure the utility's customer service performance, which may include the average length of time to answer a customer's call by a customer service representative, the abandoned call rate and the relative ranking of the electric utility, by a reputable third-party organization, in customer service satisfaction when compared to other similar electric utilities in the Midwest region.

(B) Performance metrics shall include a description of the metric, a calculation method, a data collection method, annual performance targets, and any incentives or penalties for the utility's achievement of, or failure to achieve, their performance targets, provided that the total amount of potential incentives and penalties shall be symmetrical. Incentives shall be rewards or penalties or both, reflected as basis points added to, or subtracted from, the utility's cost of equity. The metrics and incentives shall apply for the entire time period covered by a Multi-Year Rate Plan. The total for all metrics shall be equal to 40 basis points, however, the Commission may adjust the basis points upward or downward by up to 20 basis points for any given Multi-Year Rate Plan, as appropriate, but in no event may the total exceed 60 basis points or fall below 20 basis points.

(C) Metrics related to reliability shall be implemented to ensure equitable benefits to environmental justice and equity investment eligible communities, as defined in this Act.

(D) The Commission shall approve performance metrics that are reasonably within control of the utility to achieve. The Commission also shall not approve a metric that is solely expected to have the effect of reducing the workforce. Performance metrics should measure outcomes and actual, rather than projected, results where possible. Nothing in this paragraph is intended to require that different electric utilities must be subject to the same metrics, goals, or incentives.

(E) Increases or enhancements to an existing performance goal or target shall be considered in light of other metrics, cost-effectiveness, and other factors the Commission deems appropriate. Performance metrics shall include one year of tracking data collected in a consistent manner, verifiable by an independent evaluator in order to establish a baseline and measure outcomes and actual results against projections where possible.

(F) For the purpose of determining reasonable performance metrics and related incentives, the Commission shall develop a methodology to calculate net benefits that includes customer and societal costs and benefits and quantifies the effect on delivery rates. In determining the appropriate level of a performance incentive, the Commission shall consider: the extent to which the amount is likely to encourage the utility to achieve the performance target in the least cost manner; the value of benefits to customers, the grid, public health and safety, and the environment from achievement of the performance target, including in particular benefits to equity investment eligible community; the affordability of customer's electric bills, including low-income customers, the utility's revenue requirement, the promotion of renewable and distributed energy, and other such factors that the Commission deems appropriate. The consideration of these factors shall result in an incentive level that ensures benefits exceed costs for customers.

(G) Achievement of performance metrics are based on the assumptions that the utility will adopt or implement the technology and equipment, and make the investments to the extent reasonably necessary to achieve the goal. If the electric utility is unable to meet the performance metrics as a result of extraordinary circumstances outside of its control, including but not limited to government-declared emergencies, then the utility shall be permitted to file a petition with the Commission requesting that the utility be excused from compliance with the applicable performance goal or goals and the associated financial incentives and penalties. The burden of proof shall be on the utility, consistent with Article IX, and the utility's petition shall be supported by substantial evidence. The Commission shall, after notice and hearing, enter its order approving or denying, in whole or in part, the utility's petition based on the extent to which the utility demonstrated that its achievement of the affected metrics and performance goals was hindered by extraordinary circumstances outside of the utility's control.

(3) The Commission shall approve reasonable and appropriate tracking metrics to collect and monitor data for the purpose of measuring and reporting utility performance and for establishing future performance metrics. These additional tracking metrics shall include at least one metric from each of the following categories of performance:

(A) Minimize emissions of greenhouse gases and other air pollutants that harm human health, particularly in environmental justice and equity investment eligible communities, through minimizing total emissions by accelerating electrification of transportation, buildings and industries where such electrification results in net reductions, across all fuels and over the life of electrification measures, of greenhouse gases and other pollutants, taking into consideration the fuel mix used to produce electricity at the relevant hour and the effect of accelerating electrification on electricity delivery services rates, supply prices and peak demand, provided the revenues the utility receives from accelerating electrification of transportation, buildings and industries exceed the costs.

(B) Enhance the grid's flexibility to adapt to increased deployment of nondispatchable resources, improve the ability and performance of the grid on load balancing, and offer a variety of rate plans to match consumer consumption patterns and lower consumer bills for electricity delivery and supply.

(C) Ensure rates reflect cost savings attributable to grid modernization and utilize distributed energy resources that allow the utility to defer or forgo traditional grid investments that would otherwise be required to provide safe and reliable service.

(D) Metrics designed to create and sustain full-time-equivalent jobs and opportunities for all segments of the population and workforce, including minority-owned businesses, women-owned businesses, veteran-owned businesses, and businesses owned by a person or persons with a disability, and that do not, consistent with State and federal law, discriminate based on race or socioeconomic status as a result of this amendatory Act of the 102nd General Assembly.

(E) Maximize and prioritize the allocation of grid planning benefits to environmental justice and economically disadvantaged customers and communities, such that all metrics provide equitable benefits across the utility's service territory and maintain and improve utility customers' access to uninterrupted utility services.

(4) The Commission may establish new tracking and performance metrics in future Multi-Year Rate Plans to further measure achievement of the outcomes set forth in paragraph (2) of subsection (f) of this Section and the other goals and requirements of this Section.

(5) The Commission shall also evaluate metrics that were established in prior Multi-Year Rate Plans to determine if there has been an unanticipated material change in circumstances such that adjustments are required to improve the likelihood of the outcomes described in paragraph (2) of subsection (f). For metrics that were established in prior Multi-Year Rate Plan proceedings and that the Commission elects to continue, the design of these metrics, including the goals of tracking metrics and the targets and incentive levels and structures of performance metrics, may be adjusted pursuant to the requirements in this Section. The Commission may also change, adjust or phase out tracking and performance metrics that were established in prior Multi-Year Rate Plan proceedings if these metrics no longer meet the requirements of this Section or if they are rendered obsolete by the changing needs and technology of an evolving grid. Additionally, performance metrics that no longer require an incentive to create improved utility performance may become tracking metrics in a Multi-Year Rate Plan proceeding.

(6) The Commission shall initiate a workshop process no later than August 1, 2021, or 15 days after the effective date of this amendatory Act of the 102nd General Assembly, whichever is later, for the purpose of facilitating the development of metrics for each utility. The workshop shall be coordinated by the staff of the Commission, or a facilitator retained by staff, and shall be organized and facilitated in a manner that encourages representation from diverse stakeholders and ensures equitable opportunities for participation, without requiring formal intervention or representation by an attorney. Working with staff of the Commission the facilitator may conduct a combination of workshops specific to a utility or applicable to multiple utilities where content and stakeholders are substantially similar. The workshop process shall conclude no later than October 31, 2021. Following the workshop, the staff of the Commission, or the facilitator retained by the Staff, shall prepare and submit a report to the Commission that identifies the participants in the process, the metrics proposed during the process, any material issues that remained unresolved at the conclusions of such process, and any recommendations for workshop process improvements. Any workshop participant may file comments and reply comments in response to the Staff report.

(A) No later than January, 20, 2022, each electric utility that intends to file a petition pursuant to subsection (b) of this Section shall file a petition with the Commission seeking approval of its performance metrics, which shall include for each metric, at a minimum, (i) a detailed description, (ii) the calculation of the baseline, (iii) the performance period and overall performance goal, provided that the performance period shall not commence prior to January 1, 2024, (iv) each annual performance goal, (v) the performance adjustment, which shall be a symmetrical basis point increase or decrease to the utility's cost of equity based on the extent to which the utility achieved the annual performance goal, and (vi) the new or modified tariff mechanism that will apply the performance adjustments. The Commission shall issue its order approving, or approving with modification, the utility's proposed performance metrics no later than September 30, 2022.

(B) No later than August 1, 2025, the Commission shall initiate a workshop process that conforms to the workshop purpose and requirements of this paragraph (6) of this Section to the extent they do not conflict. The workshop process shall conclude no later than October 31, 2025, and the staff of the Commission, or the facilitator retained by the Staff, shall prepare and submit a report consistent with the requirements described in this paragraph (6) of this Section. No later than January 20, 2026, each electric utility subject to the requirements of this Section shall file a petition the reflects, and is consistent with, the components required in this paragraph (6) of this Section, and the Commission shall issue its order approving, or approving with modification, the utility's proposed performance metrics no later than September 30, 2026.

(f) On May 1 of each year, following the approval of the first Multi-Year Rate Plan and its initial year, the Commission shall open an annual performance evaluation proceeding to evaluate the utilities' performance on their metric targets during the year just completed, as well as the appropriate Annual Adjustment as defined in paragraph (6). The Commission shall determine the performance and annual adjustments to be applied through a surcharge in the following calendar year.

(1) On February 15 of each year, prior to the annual performance evaluation proceeding, each utility shall file a performance evaluation report with the Commission that includes a description of and all data supporting how the utility performed under each performance metric and an identification of any extraordinary events that adversely impacted the utility's performance.

(2) The metrics approved under this Section are based on the assumptions that the utility may fully implement the technology and equipment, and make the investments, required to achieve the metrics and performance goals. If the utility is unable to meet the metrics and performance goals because it was hindered by unanticipated technology or equipment implementation delays, government-declared emergencies, or other investment impediments, then the utility shall be permitted to file a petition with the Commission on or before the date that its report is due pursuant to paragraph (1) of this subsection (f) requesting that the utility be excused from compliance with the applicable performance goal or goals. The burden of proof shall be on the utility, consistent with Article IX, and the utility's petition shall be supported by substantial evidence. No later than 90 days after the utility files its petition, the Commission shall, after notice and hearing, enter its order approving or denying, in whole or in part, the utility's petition based on the extent to which the utility demonstrated that its achievement of the affected metrics and performance goals was hindered by unanticipated technology or equipment implementation delays, or other investment impediments, that were reasonably outside of the utility's control.

(3) The electric utility shall provide for an annual independent evaluation of its performance on metrics. The independent evaluator shall review the utility's assumptions, baselines, targets, calculation methodologies, and other relevant information, especially ensuring that the utility's data for establishing baselines matches actual performance, and shall provide a report to the Commission in each annual performance evaluation describing the results. The independent evaluator shall present this report as evidence as a nonparty participant and shall not be represented by the utility's legal counsel. The independent evaluator shall be hired through a competitive bidding process with approval of the contract by the Commission.

The Commission shall consider the report of the independent evaluator in determining the utility's achievement of performance targets. Discrepancies between the utility's assumptions, baselines, targets, or calculations and those of the independent evaluator shall be closely scrutinized by the Commission. If the Commission finds that the utility's reported data for any metric or metrics significantly and incorrectly deviates from the data reported by the independent evaluator, then the Commission shall order the utility to revise its data collection and calculation process within 60 days, with specifications where appropriate.

(4) The Commission shall, after notice and hearing in the annual performance evaluation proceeding, enter an order approving the utility's performance adjustment based on its achievement of or failure to achieve its performance targets no later than December 20 each year. The Commission-approved penalties or incentives shall be applied beginning with the next calendar year.

(5) In order to promote the transparency of utility investments during the effective period of a multi-year rate plan, inform the Commission's investigation and adjustment of rates in the annual adjustment process, and to facilitate the participation of stakeholders in the annual adjustment process, an electric utility with an effective Multi-Year Rate Plan shall, within 90 days of the close of each quarter during the Multi-Year Rate Plan period, submit to the Commission a report that summarizes the additions to utility plant that were placed into service during the prior quarter, which for purposes of the report shall be the most recently closed fiscal quarter. The report shall also summarize the utility plant the electric utility projects it will place into service through the end of the calendar year in which the report is filed. The projections, estimates, plans, and forward-looking information that are provided in the reports pursuant to this paragraph (5) are for planning purposes and are intended to be illustrative of the investments that the utility proposes to make as of the time of submittal. Nothing in this paragraph (5) precludes, or is intended to limit, a utility's ability to modify and update its projections, estimates, plans, and forward-looking information previously submitted in order to reflect stakeholder input or other new or updated information and analysis, including, but not limited to, changes in specific investment needs, customer electric use patterns, customer applications and preferences, and commercially available equipment and technologies, however the utility shall explain any changes or deviations between the projected investments from the quarterly reports and actual investments in the annual report. The reports submitted pursuant to this subsection are intended to be flexible planning tools, and are expected to evolve as new information becomes available. Within 7 days of receiving a quarterly report, the Commission shall timely make such report available to the public by posting it on the Commission's website. Each quarterly report shall include the following detail:

(A) The total dollar value of the additions to utility plant placed in service during the prior quarter;

(B) A list of the major investment categories the electric utility used to manage its routine standing operational activities during the prior quarter including the total dollar amount for the work reflected in each investment category in which utility plant in service is equal to or greater than $2,000,000 for an electric utility that serves more than 3,000,000 customers in the State or $500,000 for an electric utility that serves less than 3,000,000 customers but more than 500,000 customers in the State as of the last day of the quarterly reporting period, as well as a summary description of each investment category;

(C) A list of the projects which the electric utility has identified by a unique investment tracking number for utility plant placed in service during the prior quarter for utility plant placed in service with a total dollar value as of the last day of the quarterly reporting period that is equal to or greater than $2,000,000 for an electric utility that serves more than 3,000,000 customers in the State or $500,000 for an electric utility that serves less than 3,000,000 retail customers but more than $500,000 retail customers in the State, as well as a summary of each project;

(D) The estimated total dollar value of the additions to utility plant projected to be placed in service through the end of the calendar year in which the report is filed;

(E) A list of the major investment categories the electric utility used to manage its routine standing operational activities with utility plant projected to be placed in service through the end of the calendar year in which the report is filed, including the total dollar amount for the work reflected in each investment category in which utility plant in service is projected to be equal to or greater than $2,000,000 for an electric utility that serves more than 3,000,000 customers in the State or $500,000 for an electric utility that serves less than 3,000,000 retail customers but more than 500,000 retail customers in the State, as well as a summary description of each investment category; and

(F) A list of the projects for which the electric utility has identified by a unique investment tracking number for utility plant projected to be placed in service through the end of the calendar year in which the report is filed with an estimated dollar value that is equal to or greater than $2,000,000 for an electric utility that serves more than 3,000,000 customers in the State or $500,000 for an electric utility that serves less than 3,000,000 retails customers but more than $500,000 retail customers in the State, as well as a summary description of each project.

(6) As part of the Annual Performance Adjustment, the electric utility shall submit evidence sufficient to support a determination of its actual revenue requirement for the applicable calendar year, consistent with the provisions of paragraphs (d) and (f) of this subsection. The electric utility shall bear the burden of demonstrating that its costs were prudent and reasonable, subject to the provisions of paragraph (4) of this subsection (f). The Commission's review of the electric utility's annual adjustment shall be based on the same evidentiary standards, including, but not limited to, those concerning the prudence and reasonableness of the known and measurable costs forecasted to be incurred by the utility, and the used and usefulness of the actual plant investment pursuant to Section 9-211 of this Act, that the Commission applies in a proceeding to review a filing for changes in rates pursuant to Section 9-201 of this Act. The Commission shall determine the prudence and reasonableness of the actual costs incurred by the utility during the applicable calendar year, as well as determine the original cost of plant in service as of the end of the applicable calendar year. The Commission shall then determine the Annual Adjustment, which shall mean the amount by which, the electric utility's actual revenue requirement for the applicable year of the Multi-Year Rate Plan either exceeded, or was exceeded by, the revenue requirement approved by the Commission for such calendar year, plus carrying costs calculated at the weighted average cost of capital approved for the Multi-Year Rate Plan.

The Commission's determination of the electric utility's actual revenue requirement for the applicable calendar year shall be based on:

(A) the Commission-approved used and useful, prudent and reasonable actual costs for the applicable calendar year, which shall be determined pursuant to the following criteria:

(i) The overall level of actual costs incurred during the calendar year, provided that the Commission may not allow recovery of actual costs that are more than 105% of the approved revenue requirement calculated as provided in item (ii) of this subparagraph (A), except to the extent the Commission approves a modification of the Multi-Year Rate Plan to permit such recovery.

(ii) The calculation of 105% of the revenue requirement required by this subparagraph (A) shall exclude the revenue requirement impacts of the following volatile and fluctuating variables that occurred during the year: (i) storms and weather-related events for which the utility provides sufficient evidence to demonstrate that such expenses were not foreseeable and not in control of the utility; (ii) new business; (iii) changes in interest rates; (iv) changes in taxes; (v) facility relocations; (vi) changes in pension or post-retirement benefits costs due to fluctuations in interest rates, market returns or actuarial assumptions; (vii) amortization expenses related to costs; and (viii) changes in the timing of when an expenditure or investment is made such that it is accelerated to occur during the applicable year or deferred to occur in a subsequent year.

(B) the year-end rate base;

(C) the cost of equity approved in the multi-year rate plan; and

(D) the electric utility's actual year-end capital structure, provided that the common equity ratio in such capital structure may not exceed the common equity ratio that was approved by the Commission in the Multi-Year Rate Plan.

(2) The Commission's determinations of the prudence and reasonableness of the costs incurred for the applicable year, and of the original cost of plant in service as of the end of the applicable calendar year, shall be final upon entry of the Commission's order and shall not be subject to collateral attack in any other Commission proceeding, case, docket, order, rule, or regulation; however, nothing in this Section shall prohibit a party from petitioning the Commission to rehear or appeal to the courts the order pursuant to the provisions of this Act.

(g) During the period leading to approval of the first Multi-Year Integrated Grid Plan, each electric utility will necessarily continue to invest in its distribution grid. Those investments will be subject to a determination of prudence and reasonableness consistent with Commission practice and law. Any failure to conform to the Multi-Year Integrated Grid Plan ultimately approved shall not imply imprudence or unreasonableness.

(h) After calculating the Performance Adjustment and Annual Adjustment, the Commission shall order the electric utility to collect the amount in excess of the revenue requirement from customers, or issue a refund to customers, as applicable, to be applied through a surcharge beginning with the next calendar year.

Electric utilities subject to the requirements of this Section shall be permitted to file new or revised tariffs to comply with the provisions of, and Commission orders entered pursuant to, this Section.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-108.19)

Sec. 16-108.19. Division of Integrated Distribution Planning.

(a) The Commission shall establish the Division of Integrated Distribution Planning within the Bureau of Public Utilities. The Division shall be staffed by no less than 13 professionals, including engineers, rate analysts, accountants, policy analysts, utility research and analysis analysts, cybersecurity analysts, informational technology specialists, and lawyers to review and evaluate Integrated Grid Plans, updates to Integrated Grid Plans, audits, and other duties as assigned by the Chief of the Public Utilities Bureau.

(b) The Division of Integrated Distribution Planning shall be established by January 1, 2022.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-108.20)

Sec. 16-108.20. Cost-effectiveness incentive.

(a) The General Assembly finds that it is critical to maintain this focus on utility bill affordability as the State transitions to a clean energy economy. The General Assembly accordingly finds that it may be in the public interest to incentivize electric utilities to reduce spending where practicable and where such reduction will not have an adverse impact on the State's clean energy goals; this Act's overarching objectives of efficiency, environmental quality, reliability, and equity; or the utility's achievement on its metrics.

(b) In addition to the performance metrics established and approved by the Commission pursuant to Section 16-108.18 of this Act, the Commission may also determine whether each electric utility that serves more than 500,000 retail customers in the State may also be subject to a performance metric that incentivizes the utility to make cost-effective choices and stretch to achieve cost savings for public utility customers where it can do so without adverse impact (on efficiency, environmental quality, reliability or equity).

(c) The Commission shall initiate a docket on the subject of cost-effective shared savings, and shall make a determination if it would be in the public interest and the best interest of electric utility customers to establish a performance metric that incentivizes utilities to reduce their costs while meeting all other performance metrics and addressing state goals as found in this Act.

(d) At the conclusion of the docket, if the Commission determines that such an incentive is in the best interest of consumers, the Commission shall have the authority to set a specific metric as part of the performance metric process pursuant to Section 16-108.18. Such metric shall include a determination of the percentage of the shared savings to be returned to the customers and to the utility. Such percentage shall be set so as to incentivize the utility to make savings, while providing substantial benefits to consumers.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-108.21)

Sec. 16-108.21. Accelerated repayment of excess deferred income tax.

(a) The General Assembly finds:

(1) That a portion of each utility's compensation from ratepayers is attributable to reimbursement for federal taxes paid by the utility.

(2) Due to the enactment of the 2017 Tax Cut and Jobs Act, the federal income tax rate for corporations was lowered, resulting in excess deferred income tax for distribution utilities in the State that serve more than 100,000 customers.

(3) In proceedings before the Commission, it was determined that the repayment period to ratepayers by the utilities which serve more than 100,000 customers in this State for this excess deferred income tax would be 39.5 years.

(4) The COVID-19 pandemic has harmed many customers of all rate classes in the State, and resulted in the Commission adopting a number of measures to provide relief for customers.

(5) It would be in the interest of the State for the repayment of the excess deferred income tax referenced in Commission Dockets 19-0436, 19-0387, 20-0381, and 20-0393 to be paid back to ratepayers on a timetable greatly accelerated from that set forth in the dockets.

(b) Notwithstanding the Commission Orders in Dockets 19-0436, 19-0387, 20-0381, and 20-0382, the excess deferred income tax referenced in those dockets shall be fully refunded to ratepayers by the respective utilities no later than December 31, 2025.

(c) The Commission shall initiate a docket to provide for the refunding of these excess deferred income taxes to ratepayers of the utilities referenced in those dockets, and shall set forth any necessary provisions to accomplish the reimbursement on the schedule delineated in subsection (b).

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-108.25)

Sec. 16-108.25. Tariff regarding transition in rates. Each electric utility that files a Multi-Year Rate Plan pursuant to Section 16-108.18 of this Act or a general rate case as described in this Act shall also file a tariff that sets forth the processes and procedures by which the electric utility will transition from its current rates and ratemaking mechanism to the new Multi-Year Rate Plan or a general rate case and rates that will take effect under that multi-year plan. The proposed tariff shall be consistent with the tariff approved by the Commission in Docket No. 20-0426 and covers the period until the new delivery rates are effective and all required processes and procedures described in the tariff have been completed.

Each electric utility subject to this Section shall file its proposed tariff no later than 30 days after the effective date of this amendatory Act of the 102nd General Assembly, and the Commission shall enter its order approving the tariff no later than 120 days after it was filed if the Commission finds that the proposed tariff is consistent with the tariff previously approved in Docket No. 20-0426 for the period until the new delivery rates are effective and all required processes and procedures described in the tariff have been completed. If the Commission does not so find, then the Commission shall approve the utility's tariff with those modifications that are required to make the proposed tariff consistent with the tariff approved in Docket 20-0426 until the new delivery rates are effective and all required processes and procedures described in the tariff have been completed.

An electric utility that has a tariff in effect on the effective date of this amendatory Act of the 102nd General Assembly that provides for the transition from its current rates and ratemaking mechanism to new base rates approved pursuant to Article IX of this Act, shall file a compliance tariff modifying its existing tariff to comply with the provisions of this Section. The compliance tariff shall go into effect on 45 days' notice.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-108.30)

Sec. 16-108.30. Energy Transition Assistance Fund.

(a) The Energy Transition Assistance Fund is hereby created as a special fund in the State Treasury. The Energy Transition Assistance Fund is authorized to receive moneys collected pursuant to this Section. Subject to appropriation, the Department of Commerce and Economic Opportunity shall use moneys from the Energy Transition Assistance Fund consistent with the purposes of this Act.

(b) An electric utility serving more than 500,000 customers in the State shall assess an energy transition assistance charge on all its retail customers for the Energy Transition Assistance Fund. The utility's total charge shall be set based upon the value determined by the Department of Commerce and Economic Opportunity pursuant to subsection (d) or (e), as applicable, of Section 605-1075 of the Department of Commerce and Economic Opportunity Law of the Civil Administrative Code of Illinois. For each utility, the charge shall be recovered through a single, uniform cents per kilowatt-hour charge applicable to all retail customers. For each utility, the charge shall not exceed 1.3% of the amount paid per kilowatthour by eligible retail customers during the year ending May 31, 2009.

(c) Within 75 days of the effective date of this amendatory Act of the 102nd General Assembly, each electric utility serving more than 500,000 customers in the State shall file with the Illinois Commerce Commission tariffs incorporating the energy transition assistance charge in other charges stated in such tariffs, which energy transition assistance charges shall become effective no later than the beginning of the first billing cycle that begins on or after January 1, 2022. Each electric utility serving more than 500,000 customers in the State shall, prior to the beginning of each calendar year starting with calendar year 2023, file with the Illinois Commerce Commission tariff revisions to incorporate annual revisions to the energy transition assistance charge as prescribed by the Department of Commerce and Economic Opportunity pursuant to Section 605-1075 of the Department of Commerce and Economic Opportunity Law of the Civil Administrative Code of Illinois so that such revision becomes effective no later than the beginning of the first billing cycle in each respective year.

(d) The energy transition assistance charge shall be considered a charge for public utility service.

(e) By the 20th day of the month following the month in which the charges imposed by this Section were collected, each electric utility serving more than 500,000 customers in the State shall remit to Department of Revenue all moneys received as payment of the energy transition assistance charge on a return prescribed and furnished by the Department of Revenue showing such information as the Department of Revenue may reasonably require. If a customer makes a partial payment, a public utility may apply such partial payments first to amounts owed to the utility. No customer may be subjected to disconnection of his or her utility service for failure to pay the energy transition assistance charge.

If any payment provided for in this subsection exceeds the electric utility's liabilities under this Act, as shown on an original return, the Department may authorize the electric utility to credit such excess payment against liability subsequently to be remitted to the Department under this Act, in accordance with reasonable rules adopted by the Department.

All the provisions of Sections 4, 5, 5a, 5b, 5c, 5d, 5e, 5f, 5g, 5i, 5j, 6, 6a, 6b, 6c, 7, 8, 9, 10, 11, 11a, 12, and 13 of the Retailers' Occupation Tax Act that are not inconsistent with this Act apply, as far as practicable, to the charge imposed by this Act to the same extent as if those provisions were included in this Act. References in the incorporated Sections of the Retailers' Occupation Tax Act to retailers, to sellers, or to persons engaged in the business of selling tangible personal property mean persons required to remit the charge imposed under this Act.

(f) The Department of Revenue shall deposit into the Energy Transition Assistance Fund all moneys remitted to it in accordance with this Section.

(g) The Department of Revenue may establish such rules as it deems necessary to implement this Section.

(h) The Department of Commerce and Economic Opportunity may establish such rules as it deems necessary to implement this Section.

(Source: P.A. 102-662, eff. 9-15-21; 102-1031, eff. 5-27-22.)

(220 ILCS 5/16-109)

Sec. 16-109. Unbundling of delivery services; Commission review. The General Assembly finds that the offering of delivery services will, and is intended to, facilitate the development of competition for generation services, and that competition may develop for other services currently offered on a tariffed basis by the electric utility. The Commission shall open a proceeding to investigate the need for and desirability of different or additional unbundling of delivery services for some or all electric utilities 3 years from the date that a tariff for delivery services is first approved or allowed into effect pursuant to this Section. The Commission shall open an additional proceeding to again investigate the need for and desirability of different or additional unbundling of delivery services for some or all electric utilities, 3 years after the entry of its final order in the first investigation proceeding. The Commission shall issue its final order in each investigation proceeding no later than 6 months after the proceeding is initiated. In each such proceeding the Commission shall consider, at a minimum, the effect of additional unbundling on (i) the objective of just and reasonable rates, (ii) electric utility employees, and (iii) the development of competitive markets for electric energy services in Illinois. Specific changes to the delivery services tariffs of individual electric utilities to implement findings and directives stated in an order in an investigation proceeding initiated under this Section shall be addressed through individual electric utility tariff filings. The Commission may also, in accordance with Section 16-108, upon complaint or upon its own initiative without complaint, upon reasonable notice, enter upon a hearing concerning the need and desirability of requiring additional or other unbundling of delivery services offered by electric utilities.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-109A)

Sec. 16-109A. Unbundling of prices for tariffed services; Commission investigation. In addition to the unbundling authorized under Sections 16-108 and 16-109, the Commission shall have the authority to investigate the need for, and to require, the restructuring or unbundling of prices for tariffed services, other than delivery services, offered by an electric utility; provided, however, that the Commission shall not enter an order requiring the restructuring or unbundling of prices for any such tariffed services for a customer class of an electric utility prior to the date that the class first becomes eligible for delivery services pursuant to Section 16-104.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-110)

Sec. 16-110. Delivery services customer power purchase options.

(a) Each electric utility shall offer a tariffed service or services in accordance with the terms and conditions set forth in this Section pursuant to which its non-residential delivery services customers may purchase from the electric utility an amount of electric power and energy that is equal to or less than the amounts that are delivered by such electric utility.

(b) Except as provided in subsection (o) of Section 16-112, a non-residential delivery services customer that is paying transition charges to the electric utility shall be permitted to purchase electric power and energy from the electric utility at a price or prices equal to the sum of (i) the market values that are determined for the electric utility in accordance with Section 16-112 and used by the electric utility to calculate the customer's transition charges and (ii) a fee that compensates the electric utility for any administrative costs it incurs in arranging to supply such electric power and energy. The electric utility may require that the customer purchase such electric power and energy for periods of not less than one year and may also require that the customer give up to 30 days notice for a purchase of one year's duration, and 90 days notice for a purchase of more than one year's duration. A non-residential delivery service customer exercising the option described in this subsection may sell or assign its interests in the electric power or energy that the customer has purchased. In the case of any such assignment or sale by any non-residential delivery service customer to an alternative retail electric supplier that is serving such customer and has been certified pursuant to Section 16-115, an electric utility serving more than 500,000 customers shall provide such power and energy at the same market value as set forth in clause (i) of this subsection, together with the fee charged under clause (ii) of this subsection, less any costs included in such market value or fee with respect to retail marketing activities, provided, however, that in no event shall an electric utility be required after June 1, 2002 to provide power and energy at this market value plus fee that excludes marketing costs for any such assignment or sale by a non-residential customer to an alternative retail electric supplier. At least twice per year, each electric utility shall notify its small commercial retail customers, through bill inserts and other similar means, of their option to obtain electric power and energy through purchases at market value pursuant to this subsection.

(c) After the transition charge period applicable to a non-residential delivery services customer, and until the provision of electric power and energy is declared competitive for the customer group to which the customer belongs, a non-residential delivery services customer that paid any transition charges it was legally obligated to pay to an electric utility shall be permitted to purchase electric power and energy from the electric utility for contract periods of one year at a price or prices equal to the sum of (i) the market value determined for that customer's class pursuant to Section 16-112 and (ii) to the extent it is not included in such market value, a fee to compensate the electric utility for the service of arranging the supply or purchase of such electric power and energy. The electric utility may require that a delivery services customer give the following notice for such a purchase: (i) for a small commercial retail customer, not more than 30 days; (ii) for a nonresidential customer which is not a small commercial retail customer but which has maximum electrical demand of less than 500 kilowatts, not more than 6 months; (iii) for a nonresidential customer with maximum electrical demand of 500 kilowatts or more but less than one megawatt, not more than 9 months; and (iv) for a nonresidential customer with maximum electrical demand of one megawatt or more, not more than one year. At least twice per year, each electric utility shall notify its small commercial retail customers, through bill inserts or other similar means, of their option to obtain electric power and energy through purchases at market value pursuant to this subsection.

(d) After the transition charge period applicable to a non-residential delivery services customer, and until the provision of electric power and energy is declared competitive for the customer group to which the customer belongs, a non-residential delivery services customer, other than a small commercial retail customer, that paid any transition charges it was legally obligated to pay to an electric utility shall be permitted to purchase electric power and energy from the electric utility for contract periods of one year at a price or prices equal to (A) the sum of (i) the electric utility's actual cost of procuring such electric power and energy and (ii) a broker's fee to compensate the electric utility for arranging the supply, or, if the utility so elects, (B) the market value of electric power or energy provided by the electric utility determined as set forth in the electric utility's tariff for that customer's class. The electric utility may require that the delivery services customer give up to 30 days notice for such a purchase.

(e) Each delivery services customer purchasing electric power and energy from the electric utility pursuant to a tariff filed in accordance with this Section shall also pay all of the applicable charges set forth in the electric utility's delivery services tariffs and any other tariffs applicable to the services provided to that customer by the electric utility.

(f) An electric utility can require a retail customer taking delivery services that formerly generated electric power and energy for its own use and that would not otherwise pay transition charges on a portion of its electric power and energy requirements served on delivery services to pay transition charges on that portion of the customer's electric power and energy requirements as a condition of exercising the delivery services customer power purchase options set forth in this Section.

(Source: P.A. 90-561, eff. 12-16-97; 91-50, eff. 6-30-99.)

(220 ILCS 5/16-111)

Sec. 16-111. Rates and restructuring transactions during mandatory transition period; restructuring and other transactions.

(a) During the mandatory transition period, notwithstanding any provision of Article IX of this Act, and except as provided in subsections (b) and (f) of this Section, the Commission shall not (i) initiate, authorize or order any change by way of increase (other than in connection with a request for rate increase which was filed after September 1, 1997 but prior to October 15, 1997, by an electric utility serving less than 12,500 customers in this State), (ii) initiate or, unless requested by the electric utility, authorize or order any change by way of decrease, restructuring or unbundling (except as provided in Section 16-109A), in the rates of any electric utility that were in effect on October 1, 1996, or (iii) in any order approving any application for a merger pursuant to Section 7-204 that was pending as of May 16, 1997, impose any condition requiring any filing for an increase, decrease, or change in, or other review of, an electric utility's rates or enforce any such condition of any such order; provided, however, that this subsection shall not prohibit the Commission from:

(1) approving the application of an electric utility to implement an alternative to rate of return regulation or a regulatory mechanism that rewards or penalizes the electric utility through adjustment of rates based on utility performance, pursuant to Section 9-244;

(2) authorizing an electric utility to eliminate its fuel adjustment clause and adjust its base rate tariffs in accordance with subsection (b), (d), or (f) of Section 9-220 of this Act, to fix its fuel adjustment factor in accordance with subsection (c) of Section 9-220 of this Act, or to eliminate its fuel adjustment clause in accordance with subsection (e) of Section 9-220 of this Act;

(3) ordering into effect tariffs for delivery services and transition charges in accordance with Sections 16-104 and 16-108, for real-time pricing in accordance with Section 16-107, or the options required by Section 16-110 and subsection (n) of 16-112, allowing a billing experiment in accordance with Section 16-106, or modifying delivery services tariffs in accordance with Section 16-109; or

(4) ordering or allowing into effect any tariff to recover charges pursuant to Sections 9-201.5, 9-220.1, 9-221, 9-222 (except as provided in Section 9-222.1), 16-108, and 16-114 of this Act, Section 5-5 of the Electricity Infrastructure Maintenance Fee Law, Section 6-5 of the Renewable Energy, Energy Efficiency, and Coal Resources Development Law of 1997, and Section 13 of the Energy Assistance Act.

After December 31, 2004, the provisions of this subsection (a) shall not apply to an electric utility whose average residential retail rate was less than or equal to 90% of the average residential retail rate for the "Midwest Utilities", as that term is defined in subsection (b) of this Section, based on data reported on Form 1 to the Federal Energy Regulatory Commission for calendar year 1995, and which served between 150,000 and 250,000 retail customers in this State on January 1, 1995 unless the electric utility or its holding company has been acquired by or merged with an affiliate of another electric utility subsequent to January 1, 2002. This exemption shall be limited to this subsection (a) and shall not extend to any other provisions of this Act.

(b) Notwithstanding the provisions of subsection (a), each Illinois electric utility serving more than 12,500 customers in Illinois shall file tariffs (i) reducing, effective August 1, 1998, each component of its base rates to residential retail customers by 15% from the base rates in effect immediately prior to January 1, 1998 and (ii) if the public utility provides electric service to (A) more than 500,000 customers but less than 1,000,000 customers in this State on January 1, 1999, reducing, effective May 1, 2002, each component of its base rates to residential retail customers by an additional 5% from the base rates in effect immediately prior to January 1, 1998, or (B) at least 1,000,000 customers in this State on January 1, 1999, reducing, effective October 1, 2001, each component of its base rates to residential retail customers by an additional 5% from the base rates in effect immediately prior to January 1, 1998. Provided, however, that (A) if an electric utility's average residential retail rate is less than or equal to the average residential retail rate for a group of Midwest Utilities (consisting of all investor-owned electric utilities with annual system peaks in excess of 1000 megawatts in the States of Illinois, Indiana, Iowa, Kentucky, Michigan, Missouri, Ohio, and Wisconsin), based on data reported on Form 1 to the Federal Energy Regulatory Commission for calendar year 1995, then it shall only be required to file tariffs (i) reducing, effective August 1, 1998, each component of its base rates to residential retail customers by 5% from the base rates in effect immediately prior to January 1, 1998, (ii) reducing, effective October 1, 2000, each component of its base rates to residential retail customers by the lesser of 5% of the base rates in effect immediately prior to January 1, 1998 or the percentage by which the electric utility's average residential retail rate exceeds the average residential retail rate of the Midwest Utilities, based on data reported on Form 1 to the Federal Energy Regulatory Commission for calendar year 1999, and (iii) reducing, effective October 1, 2002, each component of its base rates to residential retail customers by an additional amount equal to the lesser of 5% of the base rates in effect immediately prior to January 1, 1998 or the percentage by which the electric utility's average residential retail rate exceeds the average residential retail rate of the Midwest Utilities, based on data reported on Form 1 to the Federal Energy Regulatory Commission for calendar year 2001; and (B) if the average residential retail rate of an electric utility serving between 150,000 and 250,000 retail customers in this State on January 1, 1995 is less than or equal to 90% of the average residential retail rate for the Midwest Utilities, based on data reported on Form 1 to the Federal Energy Regulatory Commission for calendar year 1995, then it shall only be required to file tariffs (i) reducing, effective August 1, 1998, each component of its base rates to residential retail customers by 2% from the base rates in effect immediately prior to January 1, 1998; (ii) reducing, effective October 1, 2000, each component of its base rates to residential retail customers by 2% from the base rate in effect immediately prior to January 1, 1998; and (iii) reducing, effective October 1, 2002, each component of its base rates to residential retail customers by 1% from the base rates in effect immediately prior to January 1, 1998. Provided, further, that any electric utility for which a decrease in base rates has been or is placed into effect between October 1, 1996 and the dates specified in the preceding sentences of this subsection, other than pursuant to the requirements of this subsection, shall be entitled to reduce the amount of any reduction or reductions in its base rates required by this subsection by the amount of such other decrease. The tariffs required under this subsection shall be filed 45 days in advance of the effective date. Notwithstanding anything to the contrary in Section 9-220 of this Act, no restatement of base rates in conjunction with the elimination of a fuel adjustment clause under that Section shall result in a lesser decrease in base rates than customers would otherwise receive under this subsection had the electric utility's fuel adjustment clause not been eliminated.

(c) Any utility reducing its base rates by 15% on August 1, 1998 pursuant to subsection (b) shall include the following statement on its bills for residential customers from August 1 through December 31, 1998: "Effective August 1, 1998, your rates have been reduced by 15% by the Electric Service Customer Choice and Rate Relief Law of 1997 passed by the Illinois General Assembly.". Any utility reducing its base rates by 5% on August 1, 1998, pursuant to subsection (b) shall include the following statement on its bills for residential customers from August 1 through December 31, 1998: "Effective August 1, 1998, your rates have been reduced by 5% by the Electric Service Customer Choice and Rate Relief Law of 1997 passed by the Illinois General Assembly.".

Any utility reducing its base rates by 2% on August 1, 1998 pursuant to subsection (b) shall include the following statement on its bills for residential customers from August 1 through December 31, 1998: "Effective August 1, 1998, your rates have been reduced by 2% by the Electric Service Customer Choice and Rate Relief Law of 1997 passed by the Illinois General Assembly.".

(d) (Blank.)

(e) (Blank.)

(f) During the mandatory transition period, an electric utility may file revised tariffs reducing the price of any tariffed service offered by the electric utility for all customers taking that tariffed service, which shall be effective 7 days after filing.

(g) Until all classes of tariffed services are declared competitive, an electric utility may, without obtaining any approval of the Commission other than that provided for in this subsection and notwithstanding any other provision of this Act or any rule or regulation of the Commission that would require such approval:

(1) implement a reorganization, other than a merger of 2 or more public utilities as defined in Section 3-105 or their holding companies;

(2) retire generating plants from service;

(3) sell, assign, lease or otherwise transfer assets to an affiliated or unaffiliated entity and as part of such transaction enter into service agreements, power purchase agreements, or other agreements with the transferee; provided, however, that the prices, terms and conditions of any power purchase agreement must be approved or allowed into effect by the Federal Energy Regulatory Commission; or

(4) use any accelerated cost recovery method including accelerated depreciation, accelerated amortization or other capital recovery methods, or record reductions to the original cost of its assets.

In order to implement a reorganization, retire generating plants from service, or sell, assign, lease or otherwise transfer assets pursuant to this Section, the electric utility shall comply with subsections (c) and (d) of Section 16-128, if applicable, and subsection (k) of this Section, if applicable, and provide the Commission with at least 30 days notice of the proposed reorganization or transaction, which notice shall include the following information:

(i) a complete statement of the entries that the electric utility will make on its books and records of account to implement the proposed reorganization or transaction together with a certification from an independent certified public accountant that such entries are in accord with generally accepted accounting principles and, if the Commission has previously approved guidelines for cost allocations between the utility and its affiliates, a certification from the chief accounting officer of the utility that such entries are in accord with those cost allocation guidelines;

(ii) a description of how the electric utility will use proceeds of any sale, assignment, lease or transfer to retire debt or otherwise reduce or recover the costs of services provided by such electric utility;

(iii) a list of all federal approvals or approvals required from departments and agencies of this State, other than the Commission, that the electric utility has or will obtain before implementing the reorganization or transaction;

(iv) an irrevocable commitment by the electric utility that it will not, as a result of the transaction, impose any stranded cost charges that it might otherwise be allowed to charge retail customers under federal law or increase the transition charges that it is otherwise entitled to collect under this Article XVI;

(v) if the electric utility proposes to sell, assign, lease or otherwise transfer a generating plant that brings the amount of net dependable generating capacity transferred pursuant to this subsection to an amount equal to or greater than 15% of the electric utility's net dependable capacity as of the effective date of this amendatory Act of 1997, and enters into a power purchase agreement with the entity to which such generating plant is sold, assigned, leased, or otherwise transferred, the electric utility also agrees, if its fuel adjustment clause has not already been eliminated, to eliminate its fuel adjustment clause in accordance with subsection (b) of Section 9-220 for a period of time equal to the length of any such power purchase agreement or successor agreement, or until January 1, 2005, whichever is longer; if the capacity of the generating plant so transferred and related power purchase agreement does not result in the elimination of the fuel adjustment clause under this subsection, and the fuel adjustment clause has not already been eliminated, the electric utility shall agree that the costs associated with the transferred plant that are included in the calculation of the rate per kilowatt-hour to be applied pursuant to the electric utility's fuel adjustment clause during such period shall not exceed the per kilowatt-hour cost associated with such generating plant included in the electric utility's fuel adjustment clause during the full calendar year preceding the transfer, with such limit to be adjusted each year thereafter by the Gross Domestic Product Implicit Price Deflator; and

(vi) in addition, if the electric utility proposes to sell, assign, or lease, (A) either (1) an amount of generating plant that brings the amount of net dependable generating capacity transferred pursuant to this subsection to an amount equal to or greater than 15% of its net dependable capacity on the effective date of this amendatory Act of 1997, or (2) one or more generating plants with a total net dependable capacity of 1100 megawatts, or (B) transmission and distribution facilities that either (1) bring the amount of transmission and distribution facilities transferred pursuant to this subsection to an amount equal to or greater than 15% of the electric utility's total depreciated original cost investment in such facilities, or (2) represent an investment of $25,000,000 in terms of total depreciated original cost, the electric utility shall provide, in addition to the information listed in subparagraphs (i) through (v), the following information: (A) a description of how the electric utility will meet its service obligations under this Act in a safe and reliable manner and (B) the electric utility's projected earned rate of return on common equity for each year from the date of the notice through December 31, 2006 both with and without the proposed transaction. If the Commission has not issued an order initiating a hearing on the proposed transaction within 30 days after the date the electric utility's notice is filed, the transaction shall be deemed approved. The Commission may, after notice and hearing, prohibit the proposed transaction if it makes either or both of the following findings: (1) that the proposed transaction will render the electric utility unable to provide its tariffed services in a safe and reliable manner, or (2) that there is a strong likelihood that consummation of the proposed transaction will result in the electric utility being entitled to request an increase in its base rates. Any hearing initiated by the Commission into the proposed transaction shall be completed, and the Commission's final order approving or prohibiting the proposed transaction shall be entered, within 90 days after the date the electric utility's notice was filed. Provided, however, that a sale, assignment, or lease of transmission facilities to an independent system operator that meets the requirements of Section 16-126 shall not be subject to Commission approval under this Section.

In any proceeding conducted by the Commission pursuant to this subparagraph (vi), intervention shall be limited to parties with a direct interest in the transaction which is the subject of the hearing and any statutory consumer protection agency as defined in subsection (d) of Section 9-102.1. Notwithstanding the provisions of Section 10-113 of this Act, any application seeking rehearing of an order issued under this subparagraph (vi), whether filed by the electric utility or by an intervening party, shall be filed within 10 days after service of the order.

The Commission shall not in any subsequent proceeding or otherwise, review such a reorganization or other transaction authorized by this Section, but shall retain the authority to allocate costs as stated in Section 16-111(i). An entity to which an electric utility sells, assigns, leases or transfers assets pursuant to this subsection (g) shall not, as a result of the transactions specified in this subsection (g), be deemed a public utility as defined in Section 3-105. Nothing in this subsection (g) shall change any requirement under the jurisdiction of the Illinois Department of Nuclear Safety including, but not limited to, the payment of fees. Nothing in this subsection (g) shall exempt a utility from obtaining a certificate pursuant to Section 8-406 of this Act for the construction of a new electric generating facility. Nothing in this subsection (g) is intended to exempt the transactions hereunder from the operation of the federal or State antitrust laws. Nothing in this subsection (g) shall require an electric utility to use the procedures specified in this subsection for any of the transactions specified herein. Any other procedure available under this Act may, at the electric utility's election, be used for any such transaction.

(h) During the mandatory transition period, the Commission shall not establish or use any rates of depreciation, which for purposes of this subsection shall include amortization, for any electric utility other than those established pursuant to subsection (c) of Section 5-104 of this Act or utilized pursuant to subsection (g) of this Section. Provided, however, that in any proceeding to review an electric utility's rates for tariffed services pursuant to Section 9-201, 9-202, 9-250 or 16-111(d) of this Act, the Commission may establish new rates of depreciation for the electric utility in the same manner provided in subsection (d) of Section 5-104 of this Act. An electric utility implementing an accelerated cost recovery method including accelerated depreciation, accelerated amortization or other capital recovery methods, or recording reductions to the original cost of its assets, pursuant to subsection (g) of this Section, shall file a statement with the Commission describing the accelerated cost recovery method to be implemented or the reduction in the original cost of its assets to be recorded. Upon the filing of such statement, the accelerated cost recovery method or the reduction in the original cost of assets shall be deemed to be approved by the Commission as though an order had been entered by the Commission.

(i) Subsequent to the mandatory transition period, the Commission, in any proceeding to establish rates and charges for tariffed services offered by an electric utility, shall consider only (1) the then current or projected revenues, costs, investments and cost of capital directly or indirectly associated with the provision of such tariffed services; (2) collection of transition charges in accordance with Sections 16-102 and 16-108 of this Act; (3) recovery of any employee transition costs as described in Section 16-128 which the electric utility is continuing to incur, including recovery of any unamortized portion of such costs previously incurred or committed, with such costs to be equitably allocated among bundled services, delivery services, and contracts with alternative retail electric suppliers; and (4) recovery of the costs associated with the electric utility's compliance with decommissioning funding requirements; and shall not consider any other revenues, costs, investments or cost of capital of either the electric utility or of any affiliate of the electric utility that are not associated with the provision of tariffed services. In setting rates for tariffed services, the Commission shall equitably allocate joint and common costs and investments between the electric utility's competitive and tariffed services. In determining the justness and reasonableness of the electric power and energy component of an electric utility's rates for tariffed services subsequent to the mandatory transition period and prior to the time that the provision of such electric power and energy is declared competitive, the Commission shall consider the extent to which the electric utility's tariffed rates for such component for each customer class exceed the market value determined pursuant to Section 16-112, and, if the electric power and energy component of such tariffed rate exceeds the market value by more than 10% for any customer class, may establish such electric power and energy component at a rate equal to the market value plus 10%.

(j) During the mandatory transition period, an electric utility may elect to transfer to a non-operating income account under the Commission's Uniform System of Accounts either or both of (i) an amount of unamortized investment tax credit that is in addition to the ratable amount which is credited to the electric utility's operating income account for the year in accordance with Section 46(f)(2) of the federal Internal Revenue Code of 1986, as in effect prior to P.L. 101-508, or (ii) "excess tax reserves", as that term is defined in Section 203(e)(2)(A) of the federal Tax Reform Act of 1986, provided that (A) the amount transferred may not exceed the amount of the electric utility's assets that were created pursuant to Statement of Financial Accounting Standards No. 71 which the electric utility has written off during the mandatory transition period, and (B) the transfer shall not be effective until approved by the Internal Revenue Service. An electric utility electing to make such a transfer shall file a statement with the Commission stating the amount and timing of the transfer for which it intends to request approval of the Internal Revenue Service, along with a copy of its proposed request to the Internal Revenue Service for a ruling. The Commission shall issue an order within 14 days after the electric utility's filing approving, subject to receipt of approval from the Internal Revenue Service, the proposed transfer.

(k) If an electric utility is selling or transferring to a single buyer 5 or more generating plants located in this State with a total net dependable capacity of 5000 megawatts or more pursuant to subsection (g) of this Section and has obtained a sale price or consideration that exceeds 200% of the book value of such plants, the electric utility must provide to the Governor, the President of the Illinois Senate, the Minority Leader of the Illinois Senate, the Speaker of the Illinois House of Representatives, and the Minority Leader of the Illinois House of Representatives no later than 15 days after filing its notice under subsection (g) of this Section or 5 days after the date on which this subsection (k) becomes law, whichever is later, a written commitment in which such electric utility agrees to expend $2 billion outside the corporate limits of any municipality with 1,000,000 or more inhabitants within such electric utility's service area, over a 6-year period beginning with the calendar year in which the notice is filed, on projects, programs, and improvements within its service area relating to transmission and distribution including, without limitation, infrastructure expansion, repair and replacement, capital investments, operations and maintenance, and vegetation management.

(l) Notwithstanding any other provision of this Act or any rule, regulation, or prior order of the Commission, a public utility providing electric and gas service may do any one or more of the following: transfer assets to, reorganize with, or merge with one or more public utilities under common holding company ownership or control in the manner prescribed in subsection (g) of this Section. No merger transaction costs, such as fees paid to attorneys, investment bankers, and other consultants, incurred in connection with a merger pursuant to this subsection (l) shall be recoverable in any subsequent rate proceeding. Approval of a merger pursuant to this subsection (l) shall not constitute approval of, or otherwise require, rate recovery of other costs incurred in connection with, or to implement the merger, such as the cost of restructuring, combining, or integrating debt, assets, or systems. Such other costs may be recovered only to the extent that the surviving utility can demonstrate that the cost savings produced by such restructuring, combination, or integration exceed the associated costs. Nothing in this subsection (l) shall impair the terms or conditions of employment or the collective bargaining rights of any employees of the utilities that are transferring assets, reorganizing, or merging.

(m) If an electric utility that on December 31, 2005 provided electric service to at least 100,000 customers in Illinois transfers assets, reorganizes, or merges under this Section, then the same provisions apply that applied during the mandatory transition period under Section 16-128.

(Source: P.A. 95-331, eff. 8-21-07; 95-481, eff. 8-28-07; 95-876, eff. 8-21-08.)

(220 ILCS 5/16-111.1)

Sec. 16-111.1. Illinois Clean Energy Community Trust.

(a) An electric utility which has sold or transferred generating facilities in a transaction to which subsection (k) of Section 16-111 applies is authorized to establish an Illinois clean energy community trust or foundation for the purposes of providing financial support and assistance to entities, public or private, within the State of Illinois including, but not limited to, units of State and local government, educational institutions, corporations, and charitable, educational, environmental and community organizations, for programs and projects that benefit the public by improving energy efficiency, developing renewable energy resources, supporting other energy related projects that improve the State's environmental quality, and supporting projects and programs intended to preserve or enhance the natural habitats and wildlife areas of the State. Provided, however, that the trust or foundation funds shall not be used for the remediation of environmentally impaired property. The trust or foundation may also assist in identifying other energy and environmental grant opportunities.

(b) Such trust or foundation shall be governed by a declaration of trust or articles of incorporation and bylaws which shall, at a minimum, provide that:

(1) There shall be 6 voting trustees of the trust or foundation, one of whom shall be appointed by the Governor, one of whom shall be appointed by the President of the Illinois Senate, one of whom shall be appointed by the Minority Leader of the Illinois Senate, one of whom shall be appointed by the Speaker of the Illinois House of Representatives, one of whom shall be appointed by the Minority Leader of the Illinois House of Representatives, and one of whom shall be appointed by the electric utility establishing the trust or foundation, provided that the voting trustee appointed by the utility shall be a representative of a recognized environmental action group selected by the utility. The Governor shall designate one of the 6 voting trustees to serve as chairman of the trust or foundation, who shall serve as chairman of the trust or foundation at the pleasure of the Governor. In addition, there shall be 5 non-voting trustees, one of whom shall be appointed by the Director of Commerce and Economic Opportunity, one of whom shall be appointed by the Director of the Illinois Environmental Protection Agency, one of whom shall be appointed by the Director of Natural Resources, and 2 of whom shall be appointed by the electric utility establishing the trust or foundation, provided that the non-voting trustee appointed by the utility shall bring financial expertise to the trust or foundation and shall have appropriate credentials therefor.

(2) All voting trustees and the non-voting trustee with financial expertise shall be entitled to compensation for their services as trustees, provided, however, that no member of the General Assembly and no employee of the electric utility establishing the trust or foundation serving as a voting trustee shall receive any compensation for his or her services as a trustee, and provided further that the compensation to the chairman of the trust shall not exceed $25,000 annually and the compensation to any other trustee shall not exceed $20,000 annually. All trustees shall be entitled to reimbursement for reasonable expenses incurred on behalf of the trust in the performance of their duties as trustees. All such compensation and reimbursements shall be paid out of the trust.

(3) Trustees shall be appointed within 30 days after the creation of the trust or foundation and shall serve for a term of 5 years commencing upon the date of their respective appointments, until their respective successors are appointed and qualified.

(4) A vacancy in the office of trustee shall be filled by the person holding the office responsible for appointing the trustee whose death or resignation creates the vacancy, and a trustee appointed to fill a vacancy shall serve the remainder of the term of the trustee whose resignation or death created the vacancy.

(5) The trust or foundation shall have an indefinite term, and shall terminate at such time as no trust assets remain.

(6) The trust or foundation shall be funded in the minimum amount of $250,000,000, with the allocation and disbursement of funds for the various purposes for which the trust or foundation is established to be determined by the trustees in accordance with the declaration of trust or the articles of incorporation and bylaws; provided, however, that this amount may be reduced by up to $25,000,000 if, at the time the trust or foundation is funded, a corresponding amount is contributed by the electric utility establishing the trust or foundation to the Board of Trustees of Southern Illinois University for the purpose of funding programs or projects related to clean coal and provided further that $25,000,000 of the amount contributed to the trust or foundation shall be available to fund programs or projects related to clean coal.

(7) The trust or foundation shall be authorized to employ an executive director and other employees, to enter into leases, contracts and other obligations on behalf of the trust or foundation, and to incur expenses that the trustees deem necessary or appropriate for the fulfillment of the purposes for which the trust or foundation is established, provided, however, that salaries and administrative expenses incurred on behalf of the trust or foundation shall not exceed $500,000 in the first fiscal year after the trust or foundation is established and shall not exceed $1,000,000 in each subsequent fiscal year.

(8) The trustees may create and appoint advisory boards or committees to assist them with the administration of the trust or foundation, and to advise and make recommendations to them regarding the contribution and disbursement of the trust or foundation funds.

(c)(1) In addition to the allocation and disbursement of funds for the purposes set forth in subsection (a) of this Section, the trustees of the trust or foundation shall annually contribute funds in amounts set forth in subparagraph (2) of this subsection to the Citizens Utility Board created by the Citizens Utility Board Act; provided, however, that any such funds shall be used solely for the representation of the interests of utility consumers before the Illinois Commerce Commission, the Federal Energy Regulatory Commission, and the Federal Communications Commission and for the provision of consumer education on utility service and prices and on benefits and methods of energy conservation. Provided, however, that no part of such funds shall be used to support (i) any lobbying activity, (ii) activities related to fundraising, (iii) advertising or other marketing efforts regarding a particular utility, or (iv) solicitation of support for, or advocacy of, a particular position regarding any specific utility or a utility's docketed proceeding.

(2) In the calendar year in which the trust or foundation is first funded, the trustees shall contribute $1,000,000 to the Citizens Utility Board within 60 days after such trust or foundation is established; provided, however, that such contribution shall be made after December 31, 1999. In each of the 6 calendar years subsequent to the first contribution, if the trust or foundation is in existence, the trustees shall contribute to the Citizens Utility Board an amount equal to the total expenditures by such organization in the prior calendar year, as set forth in the report filed by the Citizens Utility Board with the chairman of such trust or foundation as required by subparagraph (3) of this subsection. Such subsequent contributions shall be made within 30 days of submission by the Citizens Utility Board of such report to the Chairman of the trust or foundation, but in no event shall any annual contribution by the trustees to the Citizens Utility Board exceed $1,000,000. Following such 7-year period, an Illinois statutory consumer protection agency may petition the trust or foundation for contributions to fund expenditures of the type identified in paragraph (1), but in no event shall annual contributions by the trust or foundation for such expenditures exceed $1,000,000.

(3) The Citizens Utility Board shall file a report with the chairman of such trust or foundation for each year in which it expends any funds received from the trust or foundation setting forth the amount of any expenditures (regardless of the source of funds for such expenditures) for: (i) the representation of the interests of utility consumers before the Illinois Commerce Commission, the Federal Energy Regulatory Commission, and the Federal Communications Commission, and (ii) the provision of consumer education on utility service and prices and on benefits and methods of energy conservation. Such report shall separately state the total amount of expenditures for the purposes or activities identified by items (i) and (ii) of this paragraph, the name and address of the external recipient of any such expenditure, if applicable, and the specific purposes or activities (including internal purposes or activities) for which each expenditure was made. Any report required by this subsection shall be filed with the chairman of such trust or foundation no later than March 31 of the year immediately following the year for which the report is required.

(d) In addition to any other allocation and disbursement of funds in this Section, the trustees of the trust or foundation shall contribute an amount up to $125,000,000 (1) for deposit into the General Obligation Bond Retirement and Interest Fund held in the State treasury to assist in the repayment on general obligation bonds issued under subsection (d) of Section 7 of the General Obligation Bond Act, and (2) for deposit into funds administered by agencies with responsibility for environmental activities to assist in payment for environmental programs. The amount required to be contributed shall be provided to the trustees in a certification letter from the Director of the Bureau of the Budget that shall be provided no later than August 1, 2003. The payment from the trustees shall be paid to the State no later than December 31st following the receipt of the letter.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-111.2)

Sec. 16-111.2. Provisions related to proposed utility transactions.

(a) The General Assembly finds:

(1) A transaction as described in paragraph (3) of this subsection (a) will contribute to improved reliability of the electric supply system in Illinois which is one of the key purposes of the Illinois Electric Service Customer Choice and Rate Relief Law of 1997.

(2) A transaction as described in paragraph (3) of this subsection (a) is likely to promote additional investment in the existing generating assets and in the development of additional generation capacity in Illinois, and such change in ownership is in the public interest, consistent with the intent of the Illinois Electric Service Customer Choice and Rate Relief Law of 1997 and beneficial for the citizens of this State.

(3) As of the date on which this amendatory Act of 1999 becomes law, an electric utility providing service to more than 1,000,000 customers in this State has proposed to sell or transfer to a single buyer 5 or more generating plants with a total net dependable capacity of 5000 megawatts or more pursuant to subsection (g) of Section 16-111.

(4) Such electric utility anticipates receiving a sale price or consideration as a result of such transaction exceeding 200% of the book value of these plants.

(5) Such electric utility has presented to the Governor and the leaders of the General Assembly a written commitment in which such electric utility agrees to expend $2,000,000,000 outside the corporate limits of any municipality with 1,000,000 or more inhabitants within such electric utility's service area, over a 6-year period beginning with this calendar year on projects, programs and improvements within its service area relating to transmission and distribution including, without limitation, infrastructure expansion, repair and replacement, capital investments, operations and maintenance, and vegetation management.

(6) Such electric utility has committed that, if the sale or transfer contemplated by paragraph (3) of this subsection is consummated on or before December 31, 1999, the electric utility shall make contributions totaling $250,000,000 to entities within this State for, among other purposes, environmental and clean coal initiatives pursuant to Section 16-111.1, which commitment includes a contribution of $25,000,000 to the Board of Trustees of Southern Illinois University for the purpose of funding programs or projects related to clean coal.

(b) That, in light of the findings in paragraphs (1) and (2) of subsection (a) and, in this instance, the circumstances described in paragraphs (3) through (6) of subsection (a) and otherwise, the General Assembly hereby finds that allowing the generating facilities being acquired to be eligible facilities under the provisions of the National Energy Policy Act of 1992 that apply to exempt wholesale generators (A) will benefit consumers; (B) is in the public interest; and (C) does not violate the law of this State.

(c) Nothing in this Section shall have any effect on the authority of the Commission under subsection (g) of Section 16-111 of this Act.

(Source: P.A. 91-50, eff. 6-30-99.)

(220 ILCS 5/16-111.3)

Sec. 16-111.3. Transition period earnings calculations. At such time as the Board of Governors of the Federal Reserve System ceases to include the monthly average yields of 30-year U.S. Treasury bonds in its weekly H.15 Statistical Release or successor publication, the Monthly Treasury Long-Term Average Rates (25 years and above) published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication shall instead be used to establish a rate for the purpose of calculating the Index defined in subsection (e) of Section 16-111 of this Act, and at such time, such Monthly Treasury Long-Term Average Rates (25 years and above) shall also be used in place of the monthly average yields of 30-year U.S. Treasury bonds in the rate of return calculation required by subsection (d) of Section 16-111. An electric utility shall also remove the effects, if any, of any impairment due to the application of Statement of Financial Accounting Standards No. 142, which was issued in June 2001, when making the calculations required by this Section or by subsections (d) and (e) of Section 16-111.

(Source: P.A. 92-537, eff. 6-6-02.)

(220 ILCS 5/16-111.5)

Sec. 16-111.5. Provisions relating to procurement.

(a) An electric utility that on December 31, 2005 served at least 100,000 customers in Illinois shall procure power and energy for its eligible retail customers in accordance with the applicable provisions set forth in Section 1-75 of the Illinois Power Agency Act and this Section. Beginning with the delivery year commencing on June 1, 2017, such electric utility shall also procure zero emission credits from zero emission facilities in accordance with the applicable provisions set forth in Section 1-75 of the Illinois Power Agency Act, and, for years beginning on or after June 1, 2017, the utility shall procure renewable energy resources in accordance with the applicable provisions set forth in Section 1-75 of the Illinois Power Agency Act and this Section. Beginning with the delivery year commencing on June 1, 2022, an electric utility serving over 3,000,000 customers shall also procure carbon mitigation credits from carbon-free energy resources in accordance with the applicable provisions set forth in Section 1-75 of the Illinois Power Agency Act and this Section. A small multi-jurisdictional electric utility that on December 31, 2005 served less than 100,000 customers in Illinois may elect to procure power and energy for all or a portion of its eligible Illinois retail customers in accordance with the applicable provisions set forth in this Section and Section 1-75 of the Illinois Power Agency Act. This Section shall not apply to a small multi-jurisdictional utility until such time as a small multi-jurisdictional utility requests the Illinois Power Agency to prepare a procurement plan for its eligible retail customers. "Eligible retail customers" for the purposes of this Section means those retail customers that purchase power and energy from the electric utility under fixed-price bundled service tariffs, other than those retail customers whose service is declared or deemed competitive under Section 16-113 and those other customer groups specified in this Section, including self-generating customers, customers electing hourly pricing, or those customers who are otherwise ineligible for fixed-price bundled tariff service. For those customers that are excluded from the procurement plan's electric supply service requirements, and the utility shall procure any supply requirements, including capacity, ancillary services, and hourly priced energy, in the applicable markets as needed to serve those customers, provided that the utility may include in its procurement plan load requirements for the load that is associated with those retail customers whose service has been declared or deemed competitive pursuant to Section 16-113 of this Act to the extent that those customers are purchasing power and energy during one of the transition periods identified in subsection (b) of Section 16-113 of this Act.

(b) A procurement plan shall be prepared for each electric utility consistent with the applicable requirements of the Illinois Power Agency Act and this Section. For purposes of this Section, Illinois electric utilities that are affiliated by virtue of a common parent company are considered to be a single electric utility. Small multi-jurisdictional utilities may request a procurement plan for a portion of or all of its Illinois load. Each procurement plan shall analyze the projected balance of supply and demand for those retail customers to be included in the plan's electric supply service requirements over a 5-year period, with the first planning year beginning on June 1 of the year following the year in which the plan is filed. The plan shall specifically identify the wholesale products to be procured following plan approval, and shall follow all the requirements set forth in the Public Utilities Act and all applicable State and federal laws, statutes, rules, or regulations, as well as Commission orders. Nothing in this Section precludes consideration of contracts longer than 5 years and related forecast data. Unless specified otherwise in this Section, in the procurement plan or in the implementing tariff, any procurement occurring in accordance with this plan shall be competitively bid through a request for proposals process. Approval and implementation of the procurement plan shall be subject to review and approval by the Commission according to the provisions set forth in this Section. A procurement plan shall include each of the following components:

(1) Hourly load analysis. This analysis shall include:

(i) multi-year historical analysis of hourly loads;

(ii) switching trends and competitive retail market analysis;

(iii) known or projected changes to future loads; and

(iv) growth forecasts by customer class.

(2) Analysis of the impact of any demand side and renewable energy initiatives. This analysis shall include:

(i) the impact of demand response programs and energy efficiency programs, both current and projected; for small multi-jurisdictional utilities, the impact of demand response and energy efficiency programs approved pursuant to Section 8-408 of this Act, both current and projected; and

(ii) supply side needs that are projected to be offset by purchases of renewable energy resources, if any.

(3) A plan for meeting the expected load requirements that will not be met through preexisting contracts. This plan shall include:

(i) definitions of the different Illinois retail customer classes for which supply is being purchased;

(ii) the proposed mix of demand-response products for which contracts will be executed during the next year. For small multi-jurisdictional electric utilities that on December 31, 2005 served fewer than 100,000 customers in Illinois, these shall be defined as demand-response products offered in an energy efficiency plan approved pursuant to Section 8-408 of this Act. The cost-effective demand-response measures shall be procured whenever the cost is lower than procuring comparable capacity products, provided that such products shall:

(A) be procured by a demand-response provider from those retail customers included in the plan's electric supply service requirements;

(B) at least satisfy the demand-response requirements of the regional transmission organization market in which the utility's service territory is located, including, but not limited to, any applicable capacity or dispatch requirements;

(C) provide for customers' participation in the stream of benefits produced by the demand-response products;

(D) provide for reimbursement by the demand-response provider of the utility for any costs incurred as a result of the failure of the supplier of such products to perform its obligations thereunder; and

(E) meet the same credit requirements as apply to suppliers of capacity, in the applicable regional transmission organization market;

(iii) monthly forecasted system supply requirements, including expected minimum, maximum, and average values for the planning period;

(iv) the proposed mix and selection of standard wholesale products for which contracts will be executed during the next year, separately or in combination, to meet that portion of its load requirements not met through pre-existing contracts, including but not limited to monthly 5 x 16 peak period block energy, monthly off-peak wrap energy, monthly 7 x 24 energy, annual 5 x 16 energy, other standardized energy or capacity products designed to provide eligible retail customer benefits from commercially deployed advanced technologies including but not limited to high voltage direct current converter stations, as such term is defined in Section 1-10 of the Illinois Power Agency Act, whether or not such product is currently available in wholesale markets, annual off-peak wrap energy, annual 7 x 24 energy, monthly capacity, annual capacity, peak load capacity obligations, capacity purchase plan, and ancillary services;

(v) proposed term structures for each wholesale product type included in the proposed procurement plan portfolio of products; and

(vi) an assessment of the price risk, load uncertainty, and other factors that are associated with the proposed procurement plan; this assessment, to the extent possible, shall include an analysis of the following factors: contract terms, time frames for securing products or services, fuel costs, weather patterns, transmission costs, market conditions, and the governmental regulatory environment; the proposed procurement plan shall also identify alternatives for those portfolio measures that are identified as having significant price risk and mitigation in the form of additional retail customer and ratepayer price, reliability, and environmental benefits from standardized energy products delivered from commercially deployed advanced technologies, including, but not limited to, high voltage direct current converter stations, as such term is defined in Section 1-10 of the Illinois Power Agency Act, whether or not such product is currently available in wholesale markets.

(4) Proposed procedures for balancing loads. The procurement plan shall include, for load requirements included in the procurement plan, the process for (i) hourly balancing of supply and demand and (ii) the criteria for portfolio re-balancing in the event of significant shifts in load.

(5) Long-Term Renewable Resources Procurement Plan. The Agency shall prepare a long-term renewable resources procurement plan for the procurement of renewable energy credits under Sections 1-56 and 1-75 of the Illinois Power Agency Act for delivery beginning in the 2017 delivery year.

(i) The initial long-term renewable resources procurement plan and all subsequent revisions shall be subject to review and approval by the Commission. For the purposes of this Section, "delivery year" has the same meaning as in Section 1-10 of the Illinois Power Agency Act. For purposes of this Section, "Agency" shall mean the Illinois Power Agency.

(ii) The long-term renewable resources planning process shall be conducted as follows:

(A) Electric utilities shall provide a range of load forecasts to the Illinois Power Agency within 45 days of the Agency's request for forecasts, which request shall specify the length and conditions for the forecasts including, but not limited to, the quantity of distributed generation expected to be interconnected for each year.

(B) The Agency shall publish for comment the initial long-term renewable resources procurement plan no later than 120 days after the effective date of this amendatory Act of the 99th General Assembly and shall review, and may revise, the plan at least every 2 years thereafter. To the extent practicable, the Agency shall review and propose any revisions to the long-term renewable energy resources procurement plan in conjunction with the Agency's other planning and approval processes conducted under this Section. The initial long-term renewable resources procurement plan shall:

(aa) Identify the procurement programs and competitive procurement events consistent with the applicable requirements of the Illinois Power Agency Act and shall be designed to achieve the goals set forth in subsection (c) of Section 1-75 of that Act.

(bb) Include a schedule for procurements for renewable energy credits from utility-scale wind projects, utility-scale solar projects, and brownfield site photovoltaic projects consistent with subparagraph (G) of paragraph (1) of subsection (c) of Section 1-75 of the Illinois Power Agency Act.

(cc) Identify the process whereby the Agency will submit to the Commission for review and approval the proposed contracts to implement the programs required by such plan.

Copies of the initial long-term renewable resources procurement plan and all subsequent revisions shall be posted and made publicly available on the Agency's and Commission's websites, and copies shall also be provided to each affected electric utility. An affected utility and other interested parties shall have 45 days following the date of posting to provide comment to the Agency on the initial long-term renewable resources procurement plan and all subsequent revisions. All comments submitted to the Agency shall be specific, supported by data or other detailed analyses, and, if objecting to all or a portion of the procurement plan, accompanied by specific alternative wording or proposals. All comments shall be posted on the Agency's and Commission's websites. During this 45-day comment period, the Agency shall hold at least one public hearing within each utility's service area that is subject to the requirements of this paragraph (5) for the purpose of receiving public comment. Within 21 days following the end of the 45-day review period, the Agency may revise the long-term renewable resources procurement plan based on the comments received and shall file the plan with the Commission for review and approval.

(C) Within 14 days after the filing of the initial long-term renewable resources procurement plan or any subsequent revisions, any person objecting to the plan may file an objection with the Commission. Within 21 days after the filing of the plan, the Commission shall determine whether a hearing is necessary. The Commission shall enter its order confirming or modifying the initial long-term renewable resources procurement plan or any subsequent revisions within 120 days after the filing of the plan by the Illinois Power Agency.

(D) The Commission shall approve the initial long-term renewable resources procurement plan and any subsequent revisions, including expressly the forecast used in the plan and taking into account that funding will be limited to the amount of revenues actually collected by the utilities, if the Commission determines that the plan will reasonably and prudently accomplish the requirements of Section 1-56 and subsection (c) of Section 1-75 of the Illinois Power Agency Act. The Commission shall also approve the process for the submission, review, and approval of the proposed contracts to procure renewable energy credits or implement the programs authorized by the Commission pursuant to a long-term renewable resources procurement plan approved under this Section.

In approving any long-term renewable resources procurement plan after the effective date of this amendatory Act of the 102nd General Assembly, the Commission shall approve or modify the Agency's proposal for minimum equity standards pursuant to subsection (c-10) of Section 1-75 of the Illinois Power Agency Act. The Commission shall consider any analysis performed by the Agency in developing its proposal, including past performance, availability of equity eligible contractors, and availability of equity eligible persons at the time the long-term renewable resources procurement plan is approved.

(iii) The Agency or third parties contracted by the Agency shall implement all programs authorized by the Commission in an approved long-term renewable resources procurement plan without further review and approval by the Commission. Third parties shall not begin implementing any programs or receive any payment under this Section until the Commission has approved the contract or contracts under the process authorized by the Commission in item (D) of subparagraph (ii) of paragraph (5) of this subsection (b) and the third party and the Agency or utility, as applicable, have executed the contract. For those renewable energy credits subject to procurement through a competitive bid process under the plan or under the initial forward procurements for wind and solar resources described in subparagraph (G) of paragraph (1) of subsection (c) of Section 1-75 of the Illinois Power Agency Act, the Agency shall follow the procurement process specified in the provisions relating to electricity procurement in subsections (e) through (i) of this Section.

(iv) An electric utility shall recover its costs associated with the procurement of renewable energy credits under this Section and pursuant to subsection (c-5) of Section 1-75 of the Illinois Power Agency Act through an automatic adjustment clause tariff under subsection (k) or a tariff pursuant to subsection (i-5), as applicable, of Section 16-108 of this Act. A utility shall not be required to advance any payment or pay any amounts under this Section that exceed the actual amount of revenues collected by the utility under paragraph (6) of subsection (c) of Section 1-75 of the Illinois Power Agency Act, subsection (c-5) of Section 1-75 of the Illinois Power Agency Act, and subsection (k) or subsection (i-5), as applicable, of Section 16-108 of this Act, and contracts executed under this Section shall expressly incorporate this limitation.

(v) For the public interest, safety, and welfare, the Agency and the Commission may adopt rules to carry out the provisions of this Section on an emergency basis immediately following the effective date of this amendatory Act of the 99th General Assembly.

(vi) On or before July 1 of each year, the Commission shall hold an informal hearing for the purpose of receiving comments on the prior year's procurement process and any recommendations for change.

(b-5) An electric utility that as of January 1, 2019 served more than 300,000 retail customers in this State shall purchase renewable energy credits from new renewable energy facilities constructed at or adjacent to the sites of coal-fueled electric generating facilities in this State in accordance with subsection (c-5) of Section 1-75 of the Illinois Power Agency Act. Except as expressly provided in this Section, the plans and procedures for such procurements shall not be included in the procurement plans provided for in this Section, but rather shall be conducted and implemented solely in accordance with subsection (c-5) of Section 1-75 of the Illinois Power Agency Act.

(c) The provisions of this subsection (c) shall not apply to procurements conducted pursuant to subsection (c-5) of Section 1-75 of the Illinois Power Agency Act. However, the Agency may retain a procurement administrator to assist the Agency in planning and carrying out the procurement events and implementing the other requirements specified in such subsection (c-5) of Section 1-75 of the Illinois Power Agency Act, with the costs incurred by the Agency for the procurement administrator to be recovered through fees charged to applicants for selection to sell and deliver renewable energy credits to electric utilities pursuant to subsection (c-5) of Section 1-75 of the Illinois Power Agency Act. The procurement process set forth in Section 1-75 of the Illinois Power Agency Act and subsection (e) of this Section shall be administered by a procurement administrator and monitored by a procurement monitor.

(1) The procurement administrator shall:

(i) design the final procurement process in accordance with Section 1-75 of the Illinois Power Agency Act and subsection (e) of this Section following Commission approval of the procurement plan;

(ii) develop benchmarks in accordance with subsection (e)(3) to be used to evaluate bids; these benchmarks shall be submitted to the Commission for review and approval on a confidential basis prior to the procurement event;

(iii) serve as the interface between the electric utility and suppliers;

(iv) manage the bidder pre-qualification and registration process;

(v) obtain the electric utilities' agreement to the final form of all supply contracts and credit collateral agreements;

(vi) administer the request for proposals process;

(vii) have the discretion to negotiate to determine whether bidders are willing to lower the price of bids that meet the benchmarks approved by the Commission; any post-bid negotiations with bidders shall be limited to price only and shall be completed within 24 hours after opening the sealed bids and shall be conducted in a fair and unbiased manner; in conducting the negotiations, there shall be no disclosure of any information derived from proposals submitted by competing bidders; if information is disclosed to any bidder, it shall be provided to all competing bidders;

(viii) maintain confidentiality of supplier and bidding information in a manner consistent with all applicable laws, rules, regulations, and tariffs;

(ix) submit a confidential report to the Commission recommending acceptance or rejection of bids;

(x) notify the utility of contract counterparties and contract specifics; and

(xi) administer related contingency procurement events.

(2) The procurement monitor, who shall be retained by the Commission, shall:

(i) monitor interactions among the procurement administrator, suppliers, and utility;

(ii) monitor and report to the Commission on the progress of the procurement process;

(iii) provide an independent confidential report to the Commission regarding the results of the procurement event;

(iv) assess compliance with the procurement plans approved by the Commission for each utility that on December 31, 2005 provided electric service to at least 100,000 customers in Illinois and for each small multi-jurisdictional utility that on December 31, 2005 served less than 100,000 customers in Illinois;

(v) preserve the confidentiality of supplier and bidding information in a manner consistent with all applicable laws, rules, regulations, and tariffs;

(vi) provide expert advice to the Commission and consult with the procurement administrator regarding issues related to procurement process design, rules, protocols, and policy-related matters; and

(vii) consult with the procurement administrator regarding the development and use of benchmark criteria, standard form contracts, credit policies, and bid documents.

(d) Except as provided in subsection (j), the planning process shall be conducted as follows:

(1) Beginning in 2008, each Illinois utility procuring power pursuant to this Section shall annually provide a range of load forecasts to the Illinois Power Agency by July 15 of each year, or such other date as may be required by the Commission or Agency. The load forecasts shall cover the 5-year procurement planning period for the next procurement plan and shall include hourly data representing a high-load, low-load, and expected-load scenario for the load of those retail customers included in the plan's electric supply service requirements. The utility shall provide supporting data and assumptions for each of the scenarios.

(2) Beginning in 2008, the Illinois Power Agency shall prepare a procurement plan by August 15th of each year, or such other date as may be required by the Commission. The procurement plan shall identify the portfolio of demand-response and power and energy products to be procured. Cost-effective demand-response measures shall be procured as set forth in item (iii) of subsection (b) of this Section. Copies of the procurement plan shall be posted and made publicly available on the Agency's and Commission's websites, and copies shall also be provided to each affected electric utility. An affected utility shall have 30 days following the date of posting to provide comment to the Agency on the procurement plan. Other interested entities also may comment on the procurement plan. All comments submitted to the Agency shall be specific, supported by data or other detailed analyses, and, if objecting to all or a portion of the procurement plan, accompanied by specific alternative wording or proposals. All comments shall be posted on the Agency's and Commission's websites. During this 30-day comment period, the Agency shall hold at least one public hearing within each utility's service area for the purpose of receiving public comment on the procurement plan. Within 14 days following the end of the 30-day review period, the Agency shall revise the procurement plan as necessary based on the comments received and file the procurement plan with the Commission and post the procurement plan on the websites.

(3) Within 5 days after the filing of the procurement plan, any person objecting to the procurement plan shall file an objection with the Commission. Within 10 days after the filing, the Commission shall determine whether a hearing is necessary. The Commission shall enter its order confirming or modifying the procurement plan within 90 days after the filing of the procurement plan by the Illinois Power Agency.

(4) The Commission shall approve the procurement plan, including expressly the forecast used in the procurement plan, if the Commission determines that it will ensure adequate, reliable, affordable, efficient, and environmentally sustainable electric service at the lowest total cost over time, taking into account any benefits of price stability.

(4.5) The Commission shall review the Agency's recommendations for the selection of applicants to enter into long-term contracts for the sale and delivery of renewable energy credits from new renewable energy facilities to be constructed at or adjacent to the sites of coal-fueled electric generating facilities in this State in accordance with the provisions of subsection (c-5) of Section 1-75 of the Illinois Power Agency Act, and shall approve the Agency's recommendations if the Commission determines that the applicants recommended by the Agency for selection, the proposed new renewable energy facilities to be constructed, the amounts of renewable energy credits to be delivered pursuant to the contracts, and the other terms of the contracts, are consistent with the requirements of subsection (c-5) of Section 1-75 of the Illinois Power Agency Act.

(e) The procurement process shall include each of the following components:

(1) Solicitation, pre-qualification, and registration of bidders. The procurement administrator shall disseminate information to potential bidders to promote a procurement event, notify potential bidders that the procurement administrator may enter into a post-bid price negotiation with bidders that meet the applicable benchmarks, provide supply requirements, and otherwise explain the competitive procurement process. In addition to such other publication as the procurement administrator determines is appropriate, this information shall be posted on the Illinois Power Agency's and the Commission's websites. The procurement administrator shall also administer the prequalification process, including evaluation of credit worthiness, compliance with procurement rules, and agreement to the standard form contract developed pursuant to paragraph (2) of this subsection (e). The procurement administrator shall then identify and register bidders to participate in the procurement event.

(2) Standard contract forms and credit terms and instruments. The procurement administrator, in consultation with the utilities, the Commission, and other interested parties and subject to Commission oversight, shall develop and provide standard contract forms for the supplier contracts that meet generally accepted industry practices. Standard credit terms and instruments that meet generally accepted industry practices shall be similarly developed. The procurement administrator shall make available to the Commission all written comments it receives on the contract forms, credit terms, or instruments. If the procurement administrator cannot reach agreement with the applicable electric utility as to the contract terms and conditions, the procurement administrator must notify the Commission of any disputed terms and the Commission shall resolve the dispute. The terms of the contracts shall not be subject to negotiation by winning bidders, and the bidders must agree to the terms of the contract in advance so that winning bids are selected solely on the basis of price.

(3) Establishment of a market-based price benchmark. As part of the development of the procurement process, the procurement administrator, in consultation with the Commission staff, Agency staff, and the procurement monitor, shall establish benchmarks for evaluating the final prices in the contracts for each of the products that will be procured through the procurement process. The benchmarks shall be based on price data for similar products for the same delivery period and same delivery hub, or other delivery hubs after adjusting for that difference. The price benchmarks may also be adjusted to take into account differences between the information reflected in the underlying data sources and the specific products and procurement process being used to procure power for the Illinois utilities. The benchmarks shall be confidential but shall be provided to, and will be subject to Commission review and approval, prior to a procurement event.

(4) Request for proposals competitive procurement process. The procurement administrator shall design and issue a request for proposals to supply electricity in accordance with each utility's procurement plan, as approved by the Commission. The request for proposals shall set forth a procedure for sealed, binding commitment bidding with pay-as-bid settlement, and provision for selection of bids on the basis of price.

(5) A plan for implementing contingencies in the event of supplier default or failure of the procurement process to fully meet the expected load requirement due to insufficient supplier participation, Commission rejection of results, or any other cause.

(i) Event of supplier default: In the event of supplier default, the utility shall review the contract of the defaulting supplier to determine if the amount of supply is 200 megawatts or greater, and if there are more than 60 days remaining of the contract term. If both of these conditions are met, and the default results in termination of the contract, the utility shall immediately notify the Illinois Power Agency that a request for proposals must be issued to procure replacement power, and the procurement administrator shall run an additional procurement event. If the contracted supply of the defaulting supplier is less than 200 megawatts or there are less than 60 days remaining of the contract term, the utility shall procure power and energy from the applicable regional transmission organization market, including ancillary services, capacity, and day-ahead or real time energy, or both, for the duration of the contract term to replace the contracted supply; provided, however, that if a needed product is not available through the regional transmission organization market it shall be purchased from the wholesale market.

(ii) Failure of the procurement process to fully meet the expected load requirement: If the procurement process fails to fully meet the expected load requirement due to insufficient supplier participation or due to a Commission rejection of the procurement results, the procurement administrator, the procurement monitor, and the Commission staff shall meet within 10 days to analyze potential causes of low supplier interest or causes for the Commission decision. If changes are identified that would likely result in increased supplier participation, or that would address concerns causing the Commission to reject the results of the prior procurement event, the procurement administrator may implement those changes and rerun the request for proposals process according to a schedule determined by those parties and consistent with Section 1-75 of the Illinois Power Agency Act and this subsection. In any event, a new request for proposals process shall be implemented by the procurement administrator within 90 days after the determination that the procurement process has failed to fully meet the expected load requirement.

(iii) In all cases where there is insufficient supply provided under contracts awarded through the procurement process to fully meet the electric utility's load requirement, the utility shall meet the load requirement by procuring power and energy from the applicable regional transmission organization market, including ancillary services, capacity, and day-ahead or real time energy, or both; provided, however, that if a needed product is not available through the regional transmission organization market it shall be purchased from the wholesale market.

(6) The procurement processes described in this subsection and in subsection (c-5) of Section 1-75 of the Illinois Power Agency Act are exempt from the requirements of the Illinois Procurement Code, pursuant to Section 20-10 of that Code.

(f) Within 2 business days after opening the sealed bids, the procurement administrator shall submit a confidential report to the Commission. The report shall contain the results of the bidding for each of the products along with the procurement administrator's recommendation for the acceptance and rejection of bids based on the price benchmark criteria and other factors observed in the process. The procurement monitor also shall submit a confidential report to the Commission within 2 business days after opening the sealed bids. The report shall contain the procurement monitor's assessment of bidder behavior in the process as well as an assessment of the procurement administrator's compliance with the procurement process and rules. The Commission shall review the confidential reports submitted by the procurement administrator and procurement monitor, and shall accept or reject the recommendations of the procurement administrator within 2 business days after receipt of the reports.

(g) Within 3 business days after the Commission decision approving the results of a procurement event, the utility shall enter into binding contractual arrangements with the winning suppliers using the standard form contracts; except that the utility shall not be required either directly or indirectly to execute the contracts if a tariff that is consistent with subsection (l) of this Section has not been approved and placed into effect for that utility.

(h) For the procurement of standard wholesale products, the names of the successful bidders and the load weighted average of the winning bid prices for each contract type and for each contract term shall be made available to the public at the time of Commission approval of a procurement event. For procurements conducted to meet the requirements of subsection (b) of Section 1-56 or subsection (c) of Section 1-75 of the Illinois Power Agency Act governed by the provisions of this Section, the address and nameplate capacity of the new renewable energy generating facility proposed by a winning bidder shall also be made available to the public at the time of Commission approval of a procurement event, along with the business address and contact information for any winning bidder. An estimate or approximation of the nameplate capacity of the new renewable energy generating facility may be disclosed if necessary to protect the confidentiality of individual bid prices.

The Commission, the procurement monitor, the procurement administrator, the Illinois Power Agency, and all participants in the procurement process shall maintain the confidentiality of all other supplier and bidding information in a manner consistent with all applicable laws, rules, regulations, and tariffs. Confidential information, including the confidential reports submitted by the procurement administrator and procurement monitor pursuant to subsection (f) of this Section, shall not be made publicly available and shall not be discoverable by any party in any proceeding, absent a compelling demonstration of need, nor shall those reports be admissible in any proceeding other than one for law enforcement purposes.

(i) Within 2 business days after a Commission decision approving the results of a procurement event or such other date as may be required by the Commission from time to time, the utility shall file for informational purposes with the Commission its actual or estimated retail supply charges, as applicable, by customer supply group reflecting the costs associated with the procurement and computed in accordance with the tariffs filed pursuant to subsection (l) of this Section and approved by the Commission.

(j) Within 60 days following August 28, 2007 (the effective date of Public Act 95-481), each electric utility that on December 31, 2005 provided electric service to at least 100,000 customers in Illinois shall prepare and file with the Commission an initial procurement plan, which shall conform in all material respects to the requirements of the procurement plan set forth in subsection (b); provided, however, that the Illinois Power Agency Act shall not apply to the initial procurement plan prepared pursuant to this subsection. The initial procurement plan shall identify the portfolio of power and energy products to be procured and delivered for the period June 2008 through May 2009, and shall identify the proposed procurement administrator, who shall have the same experience and expertise as is required of a procurement administrator hired pursuant to Section 1-75 of the Illinois Power Agency Act. Copies of the procurement plan shall be posted and made publicly available on the Commission's website. The initial procurement plan may include contracts for renewable resources that extend beyond May 2009.

(i) Within 14 days following filing of the initial procurement plan, any person may file a detailed objection with the Commission contesting the procurement plan submitted by the electric utility. All objections to the electric utility's plan shall be specific, supported by data or other detailed analyses. The electric utility may file a response to any objections to its procurement plan within 7 days after the date objections are due to be filed. Within 7 days after the date the utility's response is due, the Commission shall determine whether a hearing is necessary. If it determines that a hearing is necessary, it shall require the hearing to be completed and issue an order on the procurement plan within 60 days after the filing of the procurement plan by the electric utility.

(ii) The order shall approve or modify the procurement plan, approve an independent procurement administrator, and approve or modify the electric utility's tariffs that are proposed with the initial procurement plan. The Commission shall approve the procurement plan if the Commission determines that it will ensure adequate, reliable, affordable, efficient, and environmentally sustainable electric service at the lowest total cost over time, taking into account any benefits of price stability.

(k) (Blank).

(k-5) (Blank).

(l) An electric utility shall recover its costs incurred under this Section and subsection (c-5) of Section 1-75 of the Illinois Power Agency Act, including, but not limited to, the costs of procuring power and energy demand-response resources under this Section and its costs for purchasing renewable energy credits pursuant to subsection (c-5) of Section 1-75 of the Illinois Power Agency Act. The utility shall file with the initial procurement plan its proposed tariffs through which its costs of procuring power that are incurred pursuant to a Commission-approved procurement plan and those other costs identified in this subsection (l), will be recovered. The tariffs shall include a formula rate or charge designed to pass through both the costs incurred by the utility in procuring a supply of electric power and energy for the applicable customer classes with no mark-up or return on the price paid by the utility for that supply, plus any just and reasonable costs that the utility incurs in arranging and providing for the supply of electric power and energy. The formula rate or charge shall also contain provisions that ensure that its application does not result in over or under recovery due to changes in customer usage and demand patterns, and that provide for the correction, on at least an annual basis, of any accounting errors that may occur. A utility shall recover through the tariff all reasonable costs incurred to implement or comply with any procurement plan that is developed and put into effect pursuant to Section 1-75 of the Illinois Power Agency Act and this Section, and for the procurement of renewable energy credits pursuant to subsection (c-5) of Section 1-75 of the Illinois Power Agency Act, including any fees assessed by the Illinois Power Agency, costs associated with load balancing, and contingency plan costs. The electric utility shall also recover its full costs of procuring electric supply for which it contracted before the effective date of this Section in conjunction with the provision of full requirements service under fixed-price bundled service tariffs subsequent to December 31, 2006. All such costs shall be deemed to have been prudently incurred. The pass-through tariffs that are filed and approved pursuant to this Section shall not be subject to review under, or in any way limited by, Section 16-111(i) of this Act. All of the costs incurred by the electric utility associated with the purchase of zero emission credits in accordance with subsection (d-5) of Section 1-75 of the Illinois Power Agency Act, all costs incurred by the electric utility associated with the purchase of carbon mitigation credits in accordance with subsection (d-10) of Section 1-75 of the Illinois Power Agency Act, and, beginning June 1, 2017, all of the costs incurred by the electric utility associated with the purchase of renewable energy resources in accordance with Sections 1-56 and 1-75 of the Illinois Power Agency Act, and all of the costs incurred by the electric utility in purchasing renewable energy credits in accordance with subsection (c-5) of Section 1-75 of the Illinois Power Agency Act, shall be recovered through the electric utility's tariffed charges applicable to all of its retail customers, as specified in subsection (k) or subsection (i-5), as applicable, of Section 16-108 of this Act, and shall not be recovered through the electric utility's tariffed charges for electric power and energy supply to its eligible retail customers.

(m) The Commission has the authority to adopt rules to carry out the provisions of this Section. For the public interest, safety, and welfare, the Commission also has authority to adopt rules to carry out the provisions of this Section on an emergency basis immediately following August 28, 2007 (the effective date of Public Act 95-481).

(n) Notwithstanding any other provision of this Act, any affiliated electric utilities that submit a single procurement plan covering their combined needs may procure for those combined needs in conjunction with that plan, and may enter jointly into power supply contracts, purchases, and other procurement arrangements, and allocate capacity and energy and cost responsibility therefor among themselves in proportion to their requirements.

(o) On or before June 1 of each year, the Commission shall hold an informal hearing for the purpose of receiving comments on the prior year's procurement process and any recommendations for change.

(p) An electric utility subject to this Section may propose to invest, lease, own, or operate an electric generation facility as part of its procurement plan, provided the utility demonstrates that such facility is the least-cost option to provide electric service to those retail customers included in the plan's electric supply service requirements. If the facility is shown to be the least-cost option and is included in a procurement plan prepared in accordance with Section 1-75 of the Illinois Power Agency Act and this Section, then the electric utility shall make a filing pursuant to Section 8-406 of this Act, and may request of the Commission any statutory relief required thereunder. If the Commission grants all of the necessary approvals for the proposed facility, such supply shall thereafter be considered as a pre-existing contract under subsection (b) of this Section. The Commission shall in any order approving a proposal under this subsection specify how the utility will recover the prudently incurred costs of investing in, leasing, owning, or operating such generation facility through just and reasonable rates charged to those retail customers included in the plan's electric supply service requirements. Cost recovery for facilities included in the utility's procurement plan pursuant to this subsection shall not be subject to review under or in any way limited by the provisions of Section 16-111(i) of this Act. Nothing in this Section is intended to prohibit a utility from filing for a fuel adjustment clause as is otherwise permitted under Section 9-220 of this Act.

(q) If the Illinois Power Agency filed with the Commission, under Section 16-111.5 of this Act, its proposed procurement plan for the period commencing June 1, 2017, and the Commission has not yet entered its final order approving the plan on or before the effective date of this amendatory Act of the 99th General Assembly, then the Illinois Power Agency shall file a notice of withdrawal with the Commission, after the effective date of this amendatory Act of the 99th General Assembly, to withdraw the proposed procurement of renewable energy resources to be approved under the plan, other than the procurement of renewable energy credits from distributed renewable energy generation devices using funds previously collected from electric utilities' retail customers that take service pursuant to electric utilities' hourly pricing tariff or tariffs and, for an electric utility that serves less than 100,000 retail customers in the State, other than the procurement of renewable energy credits from distributed renewable energy generation devices. Upon receipt of the notice, the Commission shall enter an order that approves the withdrawal of the proposed procurement of renewable energy resources from the plan. The initially proposed procurement of renewable energy resources shall not be approved or be the subject of any further hearing, investigation, proceeding, or order of any kind.

This amendatory Act of the 99th General Assembly preempts and supersedes any order entered by the Commission that approved the Illinois Power Agency's procurement plan for the period commencing June 1, 2017, to the extent it is inconsistent with the provisions of this amendatory Act of the 99th General Assembly. To the extent any previously entered order approved the procurement of renewable energy resources, the portion of that order approving the procurement shall be void, other than the procurement of renewable energy credits from distributed renewable energy generation devices using funds previously collected from electric utilities' retail customers that take service under electric utilities' hourly pricing tariff or tariffs and, for an electric utility that serves less than 100,000 retail customers in the State, other than the procurement of renewable energy credits for distributed renewable energy generation devices.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-111.5A)

Sec. 16-111.5A. Provisions relating to electric rate relief.

(a) The General Assembly finds that action must be taken in order to mitigate the 2007 electric rate increases approved for residential and certain nonresidential customers served by the State's largest electric utilities in 2007. The General Assembly further finds that although various means of providing rate relief have been proposed, including imposition of a rate freeze on the electric utilities or a tax on generation within the State, the establishment of voluntary rate relief programs provides the most immediate and certain means of providing that rate relief. Accordingly, if the residential customer electric service rates that were charged to residential customers beginning January 2, 2007 by an electric utility that on December 31, 2005 provided electric service to at least 100,000 customers in Illinois resulted in an annual increase of more than 20% in an electric utility's average rate charged to residential customers for bundled electric service, those electric utilities and their holding companies or other affiliates, and any other company owning generation in this State or its affiliates, may, notwithstanding any other provisions of this Act, and without obtaining any approvals from the Commission or any other agency, regardless of whether any such approval would otherwise be required, establish and make payments to provide funds that can be used to provide rate relief beginning on the effective date of this amendatory Act of the 95th General Assembly through July 31, 2011.

(b) For purposes of this Section, the "Ameren Utilities" means Illinois Power Company, Central Illinois Public Service Company, and Central Illinois Light Company.

(c) For purposes of this Section, the "Generators" means Exelon Generation Company, LLC; Ameren Energy Resources Generating Company; Ameren Energy Marketing Company; Ameren Energy Generating Company; MidAmerican Energy Company; Midwest Generation, LLC; and Dynegy Holdings Inc.; and may include non-utility affiliates of the entities named in this subsection.

(d) For purposes of this Section, "Rate Relief Agreements" means the 2 Rate Relief Funding Agreements, the Escrow Funding Agreement, and the Illinois Power Agency Funding Agreement that Commonwealth Edison Company, the Ameren Utilities, and Generators have entered into with the Illinois Attorney General on behalf of the People of the State of Illinois for the purpose of providing $1,001,000,000 to be used to fund rate relief programs for customers of Commonwealth Edison Company and the Ameren Utilities and for the Illinois Power Agency Trust Fund and that become effective on the effective date of this amendatory Act of the 95th General Assembly. The Rate Relief Agreements have been filed with the Illinois Secretary of State Index Department and designated as "95-GA-C01" through "95-GA-C04" inclusive. The Illinois Attorney General has the right to enforce the provisions of all of the Rate Relief Agreements on behalf of the People of the State of Illinois or the Illinois Power Agency, or both, as appropriate.

(e) Subject to the terms, conditions, and contingencies of the Rate Relief Agreements, Commonwealth Edison Company will apply a total of $488,000,000 in rate relief to residential and certain nonresidential customers from 2007 through 2010. Commonwealth Edison Company will apply bill credits for all of its residential customers in its service territory in the following amounts: $250,000,000 in 2007, $125,500,000 in 2008, and $36,000,000 in 2009. Any undisbursed rate relief funds shall be applied to the targeted programs. Commonwealth Edison Company will provide rate relief for residential and certain nonresidential customers through targeted programs in the following amounts: $33,000,000 in 2007, $18,000,000 in 2008, $15,500,000 in 2009, and $10,000,000 in 2010. Subject to the terms, conditions, and contingencies of the Rate Relief Agreements, the targeted programs for 2007 consist of the following, some of which are already underway and, in the aggregate, therefore total more than $33,000,000:

(1) an electric space heating customer relief program costing approximately $8,000,000 designed to lower the average percentage increase of residential electric space heating customers to rate increases similar to other residential customers;

(2) a summer assistance program costing approximately $10,300,000 for working families and low-income customers, including low-income seniors;

(3) a residential rate relief program costing approximately $5,500,000 for working families and low-income customers, including low-income seniors, with higher than average rate increases (over 30%);

(4) a residential special hardship program costing approximately $5,000,000 to address special circumstances and hardships;

(5) a nonresidential special hardship program costing approximately $1,500,000 to address special circumstances and hardships;

(6) a relief program for the common area accounts of apartment building owners and condominium associations costing approximately $4,500,000 designed to reduce rate increases for these customers to rate increases similar to those for residential customers and to mitigate the impact of their rate increase;

(7) a weatherization assistance program for electric space heating low-income customers costing approximately $3,900,000 designed to provide energy efficiency assistance; and

(8) energy efficiency, environmental, education, and assistance programs costing approximately $5,000,000 designed to promote the use of energy efficiency programs and services by residential customers, maintenance and upgrades of a website that allows those customers to analyze their energy usage and provides incentives for the purchase of energy efficient products, the provision of energy efficient light bulbs to residential customers at a discount, and free efficient light bulbs and other assistance to low-income customers.

Based on the outcome of these targeted programs, Commonwealth Edison Company will design and implement, subject to the terms, conditions, and contingencies of the Rate Relief Agreements, targeted programs for working families, seniors, and other customers in need in 2008, 2009, and 2010.

(f) Subject to the terms, conditions, and contingencies of the Rate Relief Agreements, the Ameren Utilities will apply a total of $488,000,000 in rate relief to residential and certain nonresidential customers from 2007 through 2010. The Ameren Utilities will apply bill credits for all of their residential customers in their service territories in the following aggregate amounts: $213,000,000 in 2007, $109,000,000 in 2008, and $78,000,000 in 2009. The Ameren Utilities will apply bill credits to certain nonresidential customers in the following aggregate amounts: $26,000,000 in 2007, $11,000,000 in 2008, and $11,000,000 in 2009. Any undisbursed rate relief funds shall be applied to the targeted programs. The Ameren Utilities will provide rate relief for residential and certain nonresidential customers through targeted programs in the following amounts: $13,500,000 in 2007, $13,500,000 in 2008, $7,500,000 in 2009, and $5,500,000 in 2010. Subject to the terms, conditions and contingencies of the Rate Relief Agreements, the targeted programs consist of the following for 2007:

(1) a cooling assistance program costing approximately $2,000,000 to provide donations to the Low Income Home Energy Assistance Program;

(2) a bill payment assistance program costing approximately $2,000,000 for working families and low-income customers, including low-income seniors;

(3) a residential special hardship program costing approximately $2,000,000 to address special circumstances and hardships;

(4) a nonresidential special hardship program costing approximately $2,000,000 to address special circumstances and hardships;

(5) a percent-of-income payment program pilot costing approximately $2,500,000 that will be designed to determine for low-income electric space heating customers if paying a percentage of income for their electricity will make electricity more affordable and promote regular paying habits;

(6) a weatherization assistance program for all electric space heating low-income customers costing approximately $1,000,000 designed to provide energy efficiency assistance;

(7) a compact fluorescent light bulb distribution program costing approximately $1,000,000 designed to provide energy efficient light bulbs to residential customers at a discount; and

(8) a municipal street lighting conversion program costing approximately $1,000,000 to convert existing street lights to more efficient lights at a discount.

Based on the outcome of these targeted programs, the Ameren Utilities will design and implement, subject to the terms, conditions, and contingencies of the Rate Relief Agreements, targeted programs for working families, seniors, and other customers in need in 2008, 2009, and 2010.

In addition, the Ameren Utilities voluntarily agree to waive outstanding late payment charges associated with unpaid electric bills for usage on and after January 2, 2007, through the September 2007 billing period.

(g) Programs that use funds that are provided by electric utilities and their holding companies or other affiliates, and any other company owning generation in this State or its affiliates, to reduce utility bills, or to otherwise offset costs incurred by the utilities in mitigating rate increases for certain customer groups, may be implemented through tariffs that are filed with and reviewed by the Commission. If a utility elects to file tariffs with the Commission to implement all or a portion of the programs, those tariffs shall, regardless of the date actually filed, be deemed accepted and approved, and shall become effective, on the effective date of this amendatory Act of the 95th General Assembly. The electric utilities whose customers benefit from the funds that are disbursed as contemplated in this Section shall file annual reports documenting the disbursement of those funds with the Commission and the Illinois Attorney General. The Commission has the authority to audit disbursement of the funds to ensure they were disbursed consistently with this Section.

(h) Nothing in this Section shall be interpreted to limit the Commission's general authority over ratemaking.

(i) Subject to the terms, conditions, and contingencies of the Rate Relief Agreements, the Generators are providing a total of $25,000,000 to the Illinois Power Agency Trust Fund.

(j) None of the contributions by Commonwealth Edison Company or the Ameren Utilities pursuant to this Section may be recovered in rates.

(k) Nothing in this Section shall be interpreted to limit the authority or right of the Illinois Attorney General, under the terms of the Rate Relief Agreements, to review or audit documents, make demands, or file suit or to take other action to enforce the provisions of the Rate Relief Agreements.

(Source: P.A. 95-481, eff. 8-28-07.)

(220 ILCS 5/16-111.5B)

Sec. 16-111.5B. Provisions relating to energy efficiency procurement.

(a) Procurement plans prepared and filed pursuant to Section 16-111.5 of this Act during the years 2012 through 2015 shall be subject to the following additional requirements:

(1) The analysis included pursuant to paragraph (2) of subsection (b) of Section 16-111.5 shall also include the impact of energy efficiency building codes or appliance standards, both current and projected.

(2) The procurement plan components described in subsection (b) of Section 16-111.5 shall also include an assessment of opportunities to expand the programs promoting energy efficiency measures that have been offered under plans approved pursuant to Section 8-103 of this Act or to implement additional cost-effective energy efficiency programs or measures.

(3) In addition to the information provided pursuant to paragraph (1) of subsection (d) of Section 16-111.5 of this Act, each Illinois utility procuring power pursuant to that Section shall annually provide to the Illinois Power Agency by July 15 of each year, or such other date as may be required by the Commission or Agency, an assessment of cost-effective energy efficiency programs or measures that could be included in the procurement plan. The assessment shall include the following:

(A) A comprehensive energy efficiency potential study for the utility's service territory that was completed within the past 3 years.

(B) Beginning in 2014, the most recent analysis submitted pursuant to Section 8-103A of this Act and approved by the Commission under subsection (f) of Section 8-103 of this Act.

(C) Identification of new or expanded cost-effective energy efficiency programs or measures that are incremental to those included in energy efficiency and demand-response plans approved by the Commission pursuant to Section 8-103 of this Act and that would be offered to all retail customers whose electric service has not been declared competitive under Section 16-113 of this Act and who are eligible to purchase power and energy from the utility under fixed-price bundled service tariffs, regardless of whether such customers actually do purchase such power and energy from the utility.

(D) Analysis showing that the new or expanded cost-effective energy efficiency programs or measures would lead to a reduction in the overall cost of electric service.

(E) Analysis of how the cost of procuring additional cost-effective energy efficiency measures compares over the life of the measures to the prevailing cost of comparable supply.

(F) An energy savings goal, expressed in megawatt-hours, for the year in which the measures will be implemented.

(G) For each expanded or new program, the estimated amount that the program may reduce the agency's need to procure supply.

In preparing such assessments, a utility shall conduct an annual solicitation process for purposes of requesting proposals from third-party vendors, the results of which shall be provided to the Agency as part of the assessment, including documentation of all bids received. The utility shall develop requests for proposals consistent with the manner in which it develops requests for proposals under plans approved pursuant to Section 8-103 of this Act, which considers input from the Agency and interested stakeholders.

(4) The Illinois Power Agency shall include in the procurement plan prepared pursuant to paragraph (2) of subsection (d) of Section 16-111.5 of this Act energy efficiency programs and measures it determines are cost-effective and the associated annual energy savings goal included in the annual solicitation process and assessment submitted pursuant to paragraph (3) of this subsection (a).

(5) Pursuant to paragraph (4) of subsection (d) of Section 16-111.5 of this Act, the Commission shall also approve the energy efficiency programs and measures included in the procurement plan, including the annual energy savings goal, if the Commission determines they fully capture the potential for all achievable cost-effective savings, to the extent practicable, and otherwise satisfy the requirements of Section 8-103 of this Act.

In the event the Commission approves the procurement of additional energy efficiency, it shall reduce the amount of power to be procured under the procurement plan to reflect the additional energy efficiency and shall direct the utility to undertake the procurement of such energy efficiency, which shall not be subject to the requirements of subsection (e) of Section 16-111.5 of this Act. The utility shall consider input from the Agency and interested stakeholders on the procurement and administration process. The requirements set forth in paragraphs (1) through (5) of this subsection (a) shall terminate after the filing of the procurement plan in 2015, and no energy efficiency shall be procured by the Agency thereafter. Energy efficiency programs approved previously under this Section shall terminate no later than December 31, 2017.

(6) An electric utility shall recover its costs incurred under this Section related to the implementation of energy efficiency programs and measures approved by the Commission in its order approving the procurement plan under Section 16-111.5 of this Act, including, but not limited to, all costs associated with complying with this Section and all start-up and administrative costs and the costs for any evaluation, measurement, and verification of the measures, from all retail customers whose electric service has not been declared competitive under Section 16-113 of this Act and who are eligible to purchase power and energy from the utility under fixed-price bundled service tariffs, regardless of whether such customers actually do purchase such power and energy from the utility through the automatic adjustment clause tariff established pursuant to Section 8-103 of this Act, provided, however, that the limitations described in subsection (d) of that Section shall not apply to the costs incurred pursuant to this Section or Section 16-111.7 of this Act.

(b) For purposes of this Section, the term "energy efficiency" shall have the meaning set forth in Section 1-10 of the Illinois Power Agency Act, and the term "cost-effective" shall have the meaning set forth in subsection (a) of Section 8-103 of this Act.

(c) The changes to this Section made by this amendatory Act of the 99th General Assembly shall not interfere with existing contracts executed under a Commission order entered under this Section.

(d)(1) For those electric utilities subject to the requirements of Section 8-103B of this Act, the contracts governing the energy efficiency programs and measures approved by the Commission in its order approving the procurement plan for the period June 1, 2016 through May 31, 2017 may be extended through December 31, 2017 so that the energy efficiency programs subject to such contracts and approved in such plan continue to be offered during the period June 1, 2017 through December 31, 2017. Each such utility is authorized to increase, on a pro rata basis, the energy savings goals and budgets approved under this Section to reflect the additional 7 months of implementation of the energy efficiency programs and measures.

(2) If the Illinois Power Agency filed with the Commission, under Section 16-111.5 of this Act, its proposed procurement plan for the period commencing June 1, 2017, and the Commission has not yet entered its final order approving such plan on or before the effective date of this amendatory Act of the 99th General Assembly, then the Illinois Power Agency shall file a notice of withdrawal with the Commission to withdraw the proposed energy efficiency programs to be approved under such plan. Upon receipt of such notice, the Commission shall enter an order that approves the withdrawal of all proposed energy efficiency programs from the plan. The initially proposed energy efficiency programs shall not be approved or be the subject of any further hearing, investigation, proceeding, or order of any kind.

(3) This amendatory Act of the 99th General Assembly preempts and supersedes any order entered by the Commission that approved the Illinois Power Agency's procurement plan for the period commencing June 1, 2017, to the extent inconsistent with the provisions of this amendatory Act of the 99th General Assembly. To the extent any such previously entered order approved energy efficiency programs under this Section, the portion of such order approving such programs shall be void, and the provisions of paragraph (1) of this subsection (d) shall apply.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-111.6)

Sec. 16-111.6. Termination of utility service to electric space-heating customers. Notwithstanding any other provision of this Act or any other law to the contrary, a public utility that, on December 31, 2005, served more than 100,000 electric customers in Illinois may not, prior to September 1, 2007, terminate electric service to a residential electric space-heating customer for non-payment. For 2007 and every year thereafter, such an electric utility shall not terminate electric service to a residential space-heating customer for non-payment from December 1 through March 31.

(Source: P.A. 95-481, eff. 8-28-07.)

(220 ILCS 5/16-111.7)

Sec. 16-111.7. On-bill financing program; electric utilities.

(a) The Illinois General Assembly finds that Illinois homes and businesses have the potential to save energy through conservation and cost-effective energy efficiency measures. Programs created pursuant to this Section will allow utility customers to purchase cost-effective energy efficiency measures, including measures set forth in a Commission-approved energy efficiency and demand-response plan under Section 8-103 or 8-103B of this Act, with no required initial upfront payment, and to pay the cost of those products and services over time on their utility bill.

(b) Notwithstanding any other provision of this Act, an electric utility serving more than 100,000 customers on January 1, 2009 shall offer a Commission-approved on-bill financing program ("program") that allows its eligible retail customers, as that term is defined in Section 16-111.5 of this Act, who own a residential single family home, duplex, or other residential building with 4 or less units, or condominium at which the electric service is being provided (i) to borrow funds from a third party lender in order to purchase electric energy efficiency measures approved under the program for installation in such home or condominium without any required upfront payment and (ii) to pay back such funds over time through the electric utility's bill. Based upon the process described in subsection (b-5) of this Section, small commercial customers who own the premises at which electric service is being provided may be included in such program. After receiving a request from an electric utility for approval of a proposed program and tariffs pursuant to this Section, the Commission shall render its decision within 120 days. If no decision is rendered within 120 days, then the request shall be deemed to be approved.

Beginning no later than December 31, 2013, an electric utility subject to this subsection (b) shall also offer its program to eligible retail customers that own multifamily residential or mixed-use buildings with no more than 50 residential units, provided, however, that such customers must either be a residential customer or small commercial customer and may not use the program in such a way that repayment of the cost of energy efficiency measures is made through tenants' utility bills. An electric utility may impose a per site loan limit not to exceed $150,000. The program, and loans issued thereunder, shall only be offered to customers of the utility that meet the requirements of this Section and that also have an electric service account at the premises where the energy efficiency measures being financed shall be installed. Beginning no later than 2 years after the effective date of this amendatory Act of the 99th General Assembly, the 50 residential unit limitation described in this paragraph shall no longer apply, and the utility shall replace the per site loan limit of $150,000 with a loan limit that correlates to a maximum monthly payment that does not exceed 50% of the customer's average utility bill over the prior 12-month period.

Beginning no later than 2 years after the effective date of this amendatory Act of the 99th General Assembly, an electric utility subject to this subsection (b) shall also offer its program to eligible retail customers that are Unit Owners' Associations, as defined in subsection (o) of Section 2 of the Condominium Property Act, or Master Associations, as defined in subsection (u) of the Condominium Property Act. However, such customers must either be residential customers or small commercial customers and may not use the program in such a way that repayment of the cost of energy efficiency measures is made through unit owners' utility bills. The program and loans issued under the program shall only be offered to customers of the utility that meet the requirements of this Section and that also have an electric service account at the premises where the energy efficiency measures being financed shall be installed.

For purposes of this Section, "small commercial customer" means, for an electric utility serving more than 3,000,000 retail customers, those customers having peak demand of less than 100 kilowatts, and, for an electric utility serving less than 3,000,000 retail customers, those customers having peak demand of less than 150 kilowatts; provided, however, that in the event the Commission, after the effective date of this amendatory Act of the 98th General Assembly, approves changes to a utility's tariffs that reflects new or revised demand criteria for the utility's customer rate classifications, then the utility may file a petition with the Commission to revise the applicable definition of a small commercial customer to reflect the new or revised demand criteria for the purposes of this Section. After notice and hearing, the Commission shall enter an order approving, or approving with modification, the revised definition within 60 days after the utility files the petition.

(b-5) Within 30 days after the effective date of this amendatory Act of the 96th General Assembly, the Commission shall convene a workshop process during which interested participants may discuss issues related to the program, including program design, eligible electric energy efficiency measures, vendor qualifications, and a methodology for ensuring ongoing compliance with such qualifications, financing, sample documents such as request for proposals, contracts and agreements, dispute resolution, pre-installment and post-installment verification, and evaluation. The workshop process shall be completed within 150 days after the effective date of this amendatory Act of the 96th General Assembly.

(c) Not later than 60 days following completion of the workshop process described in subsection (b-5) of this Section, each electric utility subject to subsection (b) of this Section shall submit a proposed program to the Commission that contains the following components:

(1) A list of recommended electric energy efficiency measures that will be eligible for on-bill financing. An eligible electric energy efficiency measure ("measure") shall be a product or service for which one or more of the following is true:

(A) (blank);

(B) the projected electricity savings (determined by rates in effect at the time of purchase) are sufficient to cover the costs of implementing the measures, including finance charges and any program fees not recovered pursuant to subsection (f) of this Section; or

(C) the product or service is included in a Commission-approved energy efficiency and demand-response plan under Section 8-103 or 8-103B of this Act.

(1.5) Beginning no later than 2 years after the effective date of this amendatory Act of the 99th General Assembly, an eligible electric energy efficiency measure (measure) shall be a product or service that qualifies under subparagraph (B) or (C) of paragraph (1) of this subsection (c) or for which one or more of the following is true:

(A) a building energy assessment, performed by an energy auditor who is certified by the Building Performance Institute or who holds a similar certification, has recommended the product or service as likely to be cost effective over the course of its installed life for the building in which the measure is to be installed; or

(B) the product or service is necessary to safely or correctly install to code or industry standard an efficiency measure, including, but not limited to, installation work; changes needed to plumbing or electrical connections; upgrades to wiring or fixtures; removal of hazardous materials; correction of leaks; changes to thermostats, controls, or similar devices; and changes to venting or exhaust necessitated by the measure. However, the costs of the product or service described in this subparagraph (B) shall not exceed 25% of the total cost of installing the measure.

(2) The electric utility shall issue a request for proposals ("RFP") to lenders for purposes of providing financing to participants to pay for approved measures. The RFP criteria shall include, but not be limited to, the interest rate, origination fees, and credit terms. The utility shall select the winning bidders based on its evaluation of these criteria, with a preference for those bids containing the rates, fees, and terms most favorable to participants;

(3) The utility shall work with the lenders selected pursuant to the RFP process, and with vendors, to establish the terms and processes pursuant to which a participant can purchase eligible electric energy efficiency measures using the financing obtained from the lender. The vendor shall explain and offer the approved financing packaging to those customers identified in subsection (b) of this Section and shall assist customers in applying for financing. As part of the process, vendors shall also provide to participants information about any other incentives that may be available for the measures.

(4) The lender shall conduct credit checks or undertake other appropriate measures to limit credit risk, and shall review and approve or deny financing applications submitted by customers identified in subsection (b) of this Section. Following the lender's approval of financing and the participant's purchase of the measure or measures, the lender shall forward payment information to the electric utility, and the utility shall add as a separate line item on the participant's utility bill a charge showing the amount due under the program each month.

(5) A loan issued to a participant pursuant to the program shall be the sole responsibility of the participant, and any dispute that may arise concerning the loan's terms, conditions, or charges shall be resolved between the participant and lender. Upon transfer of the property title for the premises at which the participant receives electric service from the utility or the participant's request to terminate service at such premises, the participant shall pay in full its electric utility bill, including all amounts due under the program, provided that this obligation may be modified as provided in subsection (g) of this Section. Amounts due under the program shall be deemed amounts owed for residential and, as appropriate, small commercial electric service.

(6) The electric utility shall remit payment in full to the lender each month on behalf of the participant. In the event a participant defaults on payment of its electric utility bill, the electric utility shall continue to remit all payments due under the program to the lender, and the utility shall be entitled to recover all costs related to a participant's nonpayment through the automatic adjustment clause tariff established pursuant to Section 16-111.8 of this Act. In addition, the electric utility shall retain a security interest in the measure or measures purchased under the program, and the utility retains its right to disconnect a participant that defaults on the payment of its utility bill.

(7) The total outstanding amount financed under the program in this subsection and subsection (c-5) of this Section shall not exceed $2.5 million for an electric utility or electric utilities under a single holding company, provided that the electric utility or electric utilities may petition the Commission for an increase in such amount. Beginning after the effective date of this amendatory Act of the 99th General Assembly, the total maximum outstanding amount financed under the program in this subsection and subsections (c-5) and (c-10) of this Section shall increase by $5,000,000 per year until such time as the total maximum outstanding amount financed reaches $20,000,000. For purposes of this Section, "maximum outstanding amount financed" means the sum of all principal that has been loaned and not yet repaid.

(c-5) Within 120 days after the effective date of this amendatory Act of the 98th General Assembly, each electric utility subject to the requirements of this Section shall submit an informational filing to the Commission that describes its plan for implementing the provisions of this amendatory Act of the 98th General Assembly on or before December 31, 2013. Such filing shall also describe how the electric utility shall coordinate its program with any gas utility or utilities that provide gas service to buildings within the electric utility's service territory so that it is practical and feasible for the owner of a multifamily building to make a single application to access loans for both gas and electric energy efficiency measures in any individual building.

(c-10) No later than 365 days after the effective date of this amendatory Act of the 99th General Assembly, each electric utility subject to the requirements of this Section shall submit an informational filing to the Commission that describes its plan for implementing the provisions of this amendatory Act of the 99th General Assembly that were incorporated into this Section. Such filing shall also include the criteria to be used by the program for determining if measures to be financed are eligible electric energy efficiency measures, as defined by paragraph (1.5) of subsection (c) of this Section.

(d) A program approved by the Commission shall also include the following criteria and guidelines for such program:

(1) guidelines for financing of measures installed under a program, including, but not limited to, RFP criteria and limits on both individual loan amounts and the duration of the loans;

(2) criteria and standards for identifying and approving measures;

(3) qualifications of vendors that will market or install measures, as well as a methodology for ensuring ongoing compliance with such qualifications;

(4) sample contracts and agreements necessary to implement the measures and program; and

(5) the types of data and information that utilities and vendors participating in the program shall collect for purposes of preparing the reports required under subsection (g) of this Section.

(e) The proposed program submitted by each electric utility shall be consistent with the provisions of this Section that define operational, financial and billing arrangements between and among program participants, vendors, lenders, and the electric utility.

(f) An electric utility shall recover all of the prudently incurred costs of offering a program approved by the Commission pursuant to this Section, including, but not limited to, all start-up and administrative costs and the costs for program evaluation. All prudently incurred costs under this Section shall be recovered from the residential and small commercial retail customer classes eligible to participate in the program through the automatic adjustment clause tariff established pursuant to Section 8-103 or 8-103B of this Act.

(g) An independent evaluation of a program shall be conducted after 3 years of the program's operation. The electric utility shall retain an independent evaluator who shall evaluate the effects of the measures installed under the program and the overall operation of the program, including, but not limited to, customer eligibility criteria and whether the payment obligation for permanent electric energy efficiency measures that will continue to provide benefits of energy savings should attach to the meter location. As part of the evaluation process, the evaluator shall also solicit feedback from participants and interested stakeholders. The evaluator shall issue a report to the Commission on its findings no later than 4 years after the date on which the program commenced, and the Commission shall issue a report to the Governor and General Assembly including a summary of the information described in this Section as well as its recommendations as to whether the program should be discontinued, continued with modification or modifications or continued without modification, provided that any recommended modifications shall only apply prospectively and to measures not yet installed or financed.

(h) An electric utility offering a Commission-approved program pursuant to this Section shall not be required to comply with any other statute, order, rule, or regulation of this State that may relate to the offering of such program, provided that nothing in this Section is intended to limit the electric utility's obligation to comply with this Act and the Commission's orders, rules, and regulations, including Part 280 of Title 83 of the Illinois Administrative Code.

(i) The source of a utility customer's electric supply shall not disqualify a customer from participation in the utility's on-bill financing program. Customers of alternative retail electric suppliers may participate in the program under the same terms and conditions applicable to the utility's supply customers.

(Source: P.A. 98-586, eff. 8-27-13; 99-906, eff. 6-1-17.)

(220 ILCS 5/16-111.8)

Sec. 16-111.8. Automatic adjustment clause tariff; uncollectibles.

(a) An electric utility shall be permitted, at its election, to recover through an automatic adjustment clause tariff the incremental difference between its actual uncollectible amount as set forth in Account 904 in the utility's most recent annual FERC Form 1 and the uncollectible amount included in the utility's rates for the period reported in such annual FERC Form 1. The Commission may, in a proceeding to review a general rate case filed subsequent to the effective date of the tariff established under this Section, prospectively switch from using the actual uncollectible amount set forth in Account 904 to using net write-offs in such tariff, but only if net write-offs are also used to determine the utility's uncollectible amount in rates. In the event the Commission requires such a change, it shall be made effective at the beginning of the first full calendar year after the new rates approved in such proceeding are first placed in effect and an adjustment shall be made, if necessary, to ensure the change does not result in double-recovery or unrecovered uncollectible amounts for any year. For purposes of this Section, "uncollectible amount" means the expense set forth in Account 904 of the utility's FERC Form 1 or cost of net write-offs as appropriate. In the event the utility's rates change during the period of time reported in its most recent annual FERC Form 1, the uncollectible amount included in the utility's rates during such period of time for purposes of this Section will be a weighted average, based on revenues earned during such period by the utility under each set of rates, of the uncollectible amount included in the utility's rates at the beginning of such period and at the end of such period. This difference may either be a charge or a credit to customers depending on whether the uncollectible amount is more or less than the uncollectible amount then included in the utility's rates.

(b) The tariff may be established outside the context of a general rate case filing and shall specify the terms of any applicable audit. The Commission shall review and by order approve, or approve as modified, the proposed tariff within 180 days after the date on which it is filed. Charges and credits under the tariff shall be allocated to the appropriate customer class or classes. In addition, customers who purchase their electric supply from an alternative retail electric supplier shall not be charged by the utility for uncollectible amounts associated with electric supply provided by the utility to the utility's customers, provided that nothing in this Section is intended to affect or alter the rights and obligations imposed pursuant to Section 16-118 of this Act and any Commission order issued thereunder. Upon approval of the tariff, the utility shall, based on the 2008 FERC Form 1, apply the appropriate credit or charge based on the full year 2008 amounts for the remainder of the 2010 calendar year. Starting with the 2009 FERC Form 1 reporting period and each subsequent period, the utility shall apply the appropriate credit or charge over a 12-month period beginning with the June billing period and ending with the May billing period, with the first such billing period beginning June 2010.

(c) The approved tariff shall provide that the utility shall file a petition with the Commission annually, no later than August 31st, seeking initiation of an annual review to reconcile all amounts collected with the actual uncollectible amount in the prior period. As part of its review, the Commission shall verify that the utility collects no more and no less than its actual uncollectible amount in each applicable FERC Form 1 reporting period. The Commission shall review the prudence and reasonableness of the utility's actions to pursue minimization and collection of uncollectibles which shall include, at a minimum, the 6 enumerated criteria set forth in this Section. The Commission shall determine any required adjustments and may include suggestions for prospective changes in current practices. Nothing in this Section or the implementing tariffs shall affect or alter the electric utility's existing obligation to pursue collection of uncollectibles or the electric utility's right to disconnect service. A utility that has in effect a tariff authorized by this Section shall pursue minimization of and collection of uncollectibles through the following activities, including, but not limited to:

(1) identifying customers with late payments;

(2) contacting the customers in an effort to obtain payment;

(3) providing delinquent customers with information about possible options, including payment plans and assistance programs;

(4) serving disconnection notices;

(5) implementing disconnections based on the level of uncollectibles; and

(6) pursuing collection activities based on the level of uncollectibles.

(d) Nothing in this Section shall be construed to require a utility to immediately disconnect service for nonpayment.

(Source: P.A. 96-33, eff. 7-10-09; 96-1000, eff. 7-2-10.)

(220 ILCS 5/16-111.9)

Sec. 16-111.9. Rate relief; electricity suppliers. On and after August 14, 2009 (the effective date of Public Act 96-533), any electric utility providing rate relief pursuant to Section 16-111.5A of this Act shall not deem any residential or non-residential customer to be ineligible to receive that relief solely based upon that customer's purchase of electricity from a supplier other than that electric utility at the time the rate relief is to be credited to that customer. Nothing in this Section shall entitle customers of an electric utility that had been previously deemed ineligible prior to August 14, 2009 (the effective date of Public Act 96-533) to become eligible for rate relief credits.

(Source: P.A. 96-533, eff. 8-14-09; 96-1000, eff. 7-2-10.)

(220 ILCS 5/16-111.10)

Sec. 16-111.10. Equitable Energy Upgrade Program.

(a) The General Assembly finds and declares that Illinois homes and businesses can contribute to the creation of a clean energy economy, conservation of natural resources, and reliability of the electricity grid through the installation of cost-effective renewable energy generation, energy efficiency and demand response equipment, and energy storage systems. Further, a large portion of Illinois residents and businesses that would benefit from the installation of energy efficiency, storage, and renewable energy generation systems are unable to purchase systems due to capital or credit barriers. This State should pursue options to enable many more Illinoisans to access the health, environmental, and financial benefits of new clean energy technology.

(b) As used in this Section:

"Commission" means the Illinois Commerce Commission.

"Energy project" means renewable energy generation systems, including solar projects, energy efficiency upgrades, energy storage systems, demand response equipment, or any combination thereof.

"Fund" means the Clean Energy Jobs and Justice Fund established in the Clean Energy Jobs and Justice Fund Act.

"Program" means the Equitable Energy Upgrade Program established under subsection (c).

"Utility" means electric public utilities providing services to 500,000 or more customers under this Act.

(c) The Commission shall open an investigation into and direct all electric public utilities in this State to adopt an Equitable Energy Upgrade Program that permits customers to finance the construction of energy projects through an optional tariff payable directly through their utility bill, modeled after the Pay As You Save system, developed by the Energy Efficiency Institute. The Program model shall enable utilities to offer to make investments in energy projects to customer properties with low-cost capital and use an opt-in tariff to recover the costs. The Program shall be designed to provide customers with immediate financial savings if they choose to participate. The Program shall allow residential electric utility customers that own the property, or renters that have permission of the property owner, for which they subscribe to utility service to agree to the installation of an energy project. The Program shall ensure:

(1) eligible projects do not require upfront payments; however, customers may pay down the costs for projects with a payment to the installing contractor in order to qualify projects that would otherwise require upfront payments;

(2) eligible projects have sufficient estimated savings and estimated life span to produce significant, immediate net savings;

(3) participants shall agree the utility can recover its costs for the projects at their location by paying for the project through an optional tariff directly through the participant's electricity bill, allowing participants to benefit from installation of energy projects without traditional loans;

(4) accessibility by lower-income residents and environmental justice community residents; and

(5) the utility must ensure that customers who are interested in participating are notified that if they are income qualified, they may also be eligible for the Percentage of Income Payment Plan program and free energy improvements through other programs and provide contact information.

(d) The Commission shall establish Program guidelines with the anticipated schedule of Program availability as follows:

(1) Year 1: Beginning in the first year of operation, each utility with greater than 100,000 retail customers is required to obtain low-cost capital of at least $20,000,000 annually for investments in energy projects.

(2) Year 2: Beginning in the second year of operation, each utility with greater than 100,000 retail customers is required to obtain low-cost capital for investments in energy projects of at least $40,000,000 annually.

(3) Year 3: Beginning in the third year of operation, each utility with greater than 100,000 retail customers is required to obtain low-cost capital for investments in as many systems as customers demand, subject to available capital provided by the utility, State, or other lenders.

(e) In the design of the Program, the Commission shall:

(1) Within 270 days after the effective date of this amendatory Act of the 102nd General Assembly, convene a workshop during which interested participants may discuss issues and submit comments related to the Program.

(2) Establish Program guidelines for implementation of the Program in accordance with the Pay As You Save Essential Elements and Minimum Program Requirements that electric utilities must abide by when implementing the Program. Program guidelines established by the Commission shall include the following elements:

(A) The Commission shall establish conditions under which utilities secure capital to fund the energy projects. The Commission may allow utilities to raise capital independently, work with third-party lenders to secure the capital for participants, or a combination thereof. Any process the Commission approves must use a market mechanism to identify the least costly sources of capital funds so as to pass on maximum savings to participants. The State or the Clean Energy Jobs and Justice Fund may also provide capital for the Program.

(B) Customer protection guidelines should be designed consistent with Pay As You Save Essential Elements and Minimum Program Requirements.

(C) The Commission shall establish conditions by which utilities may connect Program participants to energy project vendors. In setting conditions for connection, the Commission may prioritize vendors that have a history of good relations with the State, including vendors that have hired participants from State-created job training programs.

(D) Guarantee that conservative estimates of financial savings will immediately and significantly exceed Program costs for Program participants.

(f) Within 120 days after the Commission releases the Program conditions established under this Section, each utility subject to the requirements of this Section shall submit an informational filing to the Commission that describes its plan for implementing the provisions of this Section. If the Commission finds that the submission does not properly comply with the statutory or regulatory requirements of the Program, the Commission may require that the utility make modifications to its filing.

(g) An independent process evaluation shall be conducted after one year of the Program's operation. An independent impact evaluation shall be conducted after 3 years of operation, excluding one-time startup costs and results from the first 12 months of the Program. The Commission shall convene an advisory council of stakeholders, including representation of low-income and environmental justice community members to make recommendations in response to the findings of the independent evaluation.

(h) The Program shall be designed using the Pay As You Save system guidelines to be cost-effective for customers. Only projects that are deemed to be cost-effective and can be reasonably expected to ensure customer savings are eligible for funding through the Program, unless, as specified in paragraph (1) of subsection (c), customers able to make upfront copayments to installers buy down the cost of projects so it can be deemed cost-effective.

(i) Eligible customers must be:

(1) property renters with permission of the property owner; or

(2) property owners.

(j) The calculation of project cost-effectiveness shall be based upon the Pay As You Save system requirements.

(1) The calculation of cost-effectiveness must be conducted by an objective process approved by the Commission and based on rates in effect at the time of installation.

(2) A project shall be considered cost-effective only if it is estimated to produce significant immediate net savings, not counting copayments voluntarily made by customers. The Commission may establish guidelines by which this required savings is estimated.

(k) The Program should be modeled after the Pay As You Save system, by which Program participants finance energy projects using the savings that the energy project creates with a tariffed on-bill program. Eligible projects shall not create personal debt for the customer, result in a lien in the event of nonpayment, or require customers to pay monthly charges for any upgrade that fails and is not repaired within 21 days. The utility may restart charges once the upgrade is repaired and functioning and extend the term of payments to recover its costs for missed payments and deferred cost recovery, providing the upgrade continues to function.

(l) Any energy project that is defective or damaged due to no fault of the participant must be either replaced or repaired with parts that meet industry standards at the cost of the utility or vendor, as specified by the Commission, and charges shall be suspended until repairs or replacement is completed. The Commission may establish, increase, or replace the requirements imposed in this subsection. The Commission may determine that this responsibility is best handled by participating project vendors in the form of insurance, contractual guarantees, or other mechanisms, and issue rules detailing this requirement. Customers shall not be charged monthly payments for upgrades that are no longer functioning.

(m) In the event of nonpayment, the remaining balance due to pay off the system shall remain with the utility meter at an upgraded location. The Commission shall establish conditions subject to this constraint in the event of nonpayment that are in accordance with the Pay As You Save system.

(n) If the demand by utility customers exceeds the Program capital supply in a given year, utilities shall ensure that 50% of participants are:

(1) customers in neighborhoods where a majority of households make 150% or less of area median income; or

(2) residents of environmental justice communities.

(o) Utilities shall endeavor to inform customers about the availability of the Program, their potential eligibility for participation in the Program, and whether they are likely to save money on the basis of an estimate conducted using variables consistent with the Program that the utility has at its disposal. The Commission may establish guidelines by which utilities must abide by this directive and alternatives if the Commission deems utilities' efforts as inadequate.

(p) Subject to Commission specifications under subsection (c), each utility shall work with certified project vendors selected using a request for proposals process to establish the terms and processes under which a utility can install eligible renewable energy generation and energy storage systems using the capital to fit the Equitable Energy Upgrade model. The certified project vendor shall explain and offer the approved upgrades to customers and shall assist customers in applying for financing through the Program. As part of the process, vendors shall also provide participants with information about any other relevant incentives that may be available.

(q) An electric utility shall recover all of the prudently incurred costs of offering a program approved by the Commission under this Section. For investor-owned utilities, shareholder incentives will be proportional to meeting Commission approved thresholds for the number of customers served and the amount of its investments in those locations.

(r) The Commission shall adopt all rules necessary for the administration of this Section.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-111.11)

Sec. 16-111.11. Supplier diversity reporting for non-utilities.

(a) The following entities shall submit an annual supplier diversity report to the Commission for a given year:

(1) entities that received a contract to provide more than 10,000 renewable energy credits approved by the Commission in a given year pursuant to subparagraph (iii) of paragraph (5) of subsection (b) of Section 16-111.5;

(2) entities that received a contract to provide more than 10,000 renewable energy credits approved by the Commission in a given year pursuant to subsection (e) of Section 16-111.5;

(3) alternative retail electric suppliers that have yearly sales in the State of 1,000,000,000 kilowatt hours or more, and alternative gas suppliers as defined in Section 19-105 that have yearly sales in the State of 1,000,000 dekatherms or more;

(4) entities constructing or operating an HVDC transmission line as defined in Section 1-10 of the Illinois Power Agency Act or entities constructing or operating transmission facilities under a certificate of public convenience and necessity issued pursuant to subsection (b-5) of Section 8-406;

(5) entities installing more than 100 energy efficiency measures with a certificate approved by the Commission pursuant to Section 16-128B; and

(6) other suppliers of electricity generated from any resource, including, but not limited to, hydro, nuclear, coal, natural gas, and any other supplier of energy within this State.

(b) An annual report filed pursuant to this Section shall be filed on an electronic form as designed by the Commission by June 1, 2023 and every June 1 thereafter, in a searchable Adobe PDF format, on all procurement goals and actual spending for women-owned businesses, minority-owned businesses, veteran-owned businesses, and small business enterprises in the previous calendar year related to the performance of obligations in the State of the contracts of licenses listed in subsection (a). These goals shall be expressed as a percentage of the total work performed by the entity submitting the report. The actual spending for all women-owned businesses, minority-owned businesses, veteran-owned businesses, and small business enterprises shall also be expressed as a percentage of the total work performed by the entity submitting the report. Notwithstanding any provision of law to the contrary, any entity with obligations related to equity eligible actions pursuant to the Illinois Power Agency Act may express such goals and spending in those terms.

Each participating entity in its annual report shall include the following information related to the entity's operations in the State related to the certificates or activities listed in subsection (a):

(1) an explanation of the plan for the next year to increase participation;

(2) an explanation of the plan to increase the goals;

(3) the areas of procurement each entity shall be actively seeking more participation in the next year;

(4) an outline of the plan to alert and encourage potential vendors in that area to seek business from the entity;

(5) an explanation of the challenges faced in finding quality vendors and offer any suggestions for what the Commission could do to be helpful to identify those vendors;

(6) a list of the certifications the entity recognizes;

(7) the point of contact for any potential vendor who wants to do business with the entity and explain the process for a vendor to enroll with the company as a minority-owned, women-owned, or veteran-owned company; and

(8) any particular success stories to encourage other entities to emulate best practices.

(c) Each annual report shall include as much State-specific data as possible. If the submitting entity does not submit State-specific data, then the entity shall include any national data it does have and explain why it could not submit State-specific data and how it intends to do so in future reports.

(d) Each annual report shall include the rules, regulations, and definitions used for the procurement goals in the entity's annual report.

(e) Each annual report filed or submitted under this Section shall be submitted with the Commission. The Commission shall not be required or authorized to compel production of any report under this Section. The Commission shall hold an annual workshop open to the public in 2024 and every year thereafter on the state of supplier diversity to collaboratively seek solutions to structural impediments to achieving stated goals, including testimony from participating entities as well as subject matter experts and advocates in a non-antagonistic manner. The Commission shall invite all entities submitting a report pursuant to this Section. The Commission shall publish a database on its website of the point of contact for each participating entity for supplier diversity, along with a list of certifications each company recognizes from the information submitted in each annual report. The Commission shall publish each annual report on its website and shall maintain each annual report for at least 5 years.

(Source: P.A. 102-1031, eff. 5-27-22.)

(220 ILCS 5/16-112)

Sec. 16-112. Determination of market value.

(a) The market value to be used in the calculation of transition charges as defined in Section 16-102 shall be determined in accordance with either (i) a tariff that has been filed by the electric utility with the Commission pursuant to Article IX of this Act and that provides for a determination of the market value for electric power and energy as a function of an exchange traded or other market traded index, options or futures contract or contracts applicable to the market in which the utility sells, and the customers in its service area buy, electric power and energy, or (ii) in the event no such tariff has been placed into effect for the electric utility, or in the event such tariff does not establish market values for each of the years specified in the neutral fact-finder process described in subsections (b) through (h) of this Section, a tariff incorporating the market values resulting from the neutral fact-finder process set forth in subsections (b) through (h) of this Section.

(b) Except as provided in subsection (m) of this Section, on or before April 30, 1998, on or before February 28, 1999, and on or before each April 30 from 2000 until 2007, the Commission shall appoint a neutral fact-finder to make the calculations described in subsection (c) of this Section. The neutral fact-finder shall be a member of a national public accounting firm, shall not have served as the neutral fact-finder in the previous year, and shall be selected from a list of candidates provided by a nationally recognized provider of neutral fact-finders that has established rules for maintaining confidentiality. An amount sufficient to pay the fees of the neutral fact-finder shall be appropriated annually from the Public Utility Fund in the State treasury.

(c) On or before June 1, 1998, on or before April 1, 1999, and on or before each June 1 from 2000 until 2007, or until discontinued in accordance with subsection (m) of this Section, each electric utility and each alternative retail electric supplier shall submit to the neutral fact-finder a summary of (A) all contracts entered into after June 1, 1997 that are for the sale of electric power and energy from a generating facility or facilities located in this State or located in a contiguous State and owned by an electric utility as part of its interconnected operating system and delivery during one or more of the 5 years succeeding the date of submission, and (B) all contracts entered into after June 1, 1997 for purchase and delivery of electric power and energy in or into this State during one or more of the 5 years succeeding the date of submission; provided, however, that such contracts shall not include (i) contracts between the electric utility and an affiliate; (ii) sales, purchases, or deliveries made under rates and tariffs filed with the Commission, except for tariffs filed pursuant to subsection (d) of Section 16-110 and except for special or negotiated rate contracts between an electric utility and a retail customer to the extent that such contracts are for the provision of electric power and energy after the date that the customer becomes eligible for delivery services; and (iii) extensions or amendments to full requirements wholesale contracts existing as of the effective date of this amendatory Act of 1997, provided that such contracts, extensions, or amendments are cost of service regulated by the Federal Energy Regulatory Commission. The summaries shall, at a minimum, identify the date of the contract; the year in which the electric power or energy is to be sold or delivered; the point of delivery; defining characteristics such as the nature of the power transaction (for example, reserve responsibility (firm, non-firm)), length of contract and temporal differences (for example, season, on-peak or off-peak); and the applicable prices stated at the point at which the electric power and energy leaves the electric utility's or alternative retail electric supplier's transmission system, as the case may be, in the case of contracts described in item (A) and at the point at which the electric power and energy enters the electric utility's transmission system in the case of contracts in item (B), provided, that the applicable price shall be stated at the point at which the electric power and energy enters the electric utility's transmission system in the case of electric power and energy generated for delivery within the electric utility's service area. In reporting to the neutral fact-finder the price of power and energy sold under bundled service contracts, electric utilities and alternative retail electric suppliers shall deduct from the contract price the charges for delivery services, including transition charges, applicable to delivery services customers in a utility's service area, and charges for services, if any, other than the provision of power and energy or delivery services. The Commission may adopt orders setting forth requirements governing the form and content of such summaries.

(d) The neutral fact-finder shall calculate market values for electric power and energy for each electric utility, taking into account the defining characteristics set forth in subsection (c) of this Section; provided, however, that the neutral fact-finder may determine that a particular value is appropriate for more than one electric utility, or for all electric utilities in this State. The neutral fact-finder shall calculate the market values for the next year and, to the extent the summaries include a sufficient number of actual contracts to represent a viable market for the sale and delivery of electric power and energy in subsequent years, for each of the 4 succeeding years.

(e) In calculating market values for electric power, the neutral fact-finder shall weight contract prices (including any contract price indices) by both the amount of capacity covered by the contract and the number of hours in which capacity is to be provided under the contract in each period of the year, shall take into account all of the defining characteristics set forth in subsection (c) of this Section and shall develop such values as required to represent the different types of market values of electric power.

(f) The neutral fact-finder shall base calculations of the market values for electric energy on the energy prices stated in the contracts, and where no explicit energy prices or index price basis are stated, on the actual energy costs of the supplier in the corresponding period of the preceding year that would have been applicable to the electric energy provided under the contract. The neutral fact-finder shall develop market values for electric energy and shall take into account the defining characteristics set forth in subsection (c) of this Section, as required to represent the market values of such electric energy.

(g) If the contracts used by the neutral fact-finder base prices for future years on one or more indices, the neutral fact-finder shall identify such indices in his or her final report, develop a weighting for each index, and calculate a weighted average index. The market values shall be calculated using the weighted average index when the actual values of the component indices are known.

(h) The neutral fact-finder shall publish a final report on or before July 30 of each year, except that in 1999 the neutral fact finder shall publish the report on or before May 30, setting forth the calculated market values and stating the basis for such calculations. The final report shall not, however, disclose any proprietary or confidential data.

(i) The market values calculated by the neutral fact-finder shall not be admissible in any proceeding for any purpose other than the calculation of transition charges or calculation of the price for the power purchase options provided pursuant to subsection (b) and (c) of Section 16-110.

(j) The Commission shall have access to all contracts described in subsection (c) of this Section and shall perform such audits as it and the neutral fact-finder deem necessary to insure the accuracy of the summaries submitted to the neutral fact-finder. The summaries described in subsection (c) of this Section and each contract shall be accorded confidential and proprietary treatment and their review shall be subject to the provisions of Sections 4-404 and 5-108 of this Act, and the contract between the Commission and the neutral fact-finder shall contain provisions obligating the neutral fact-finder to comply with such Sections. The summaries shall not be discoverable by any party in any proceeding absent a compelling demonstration of need.

(k) In determining the market values to be used for the various customer classes in calculating transition charges as defined in Section 16-102 or for the power purchase options set forth in Section 16-110, an electric utility shall apply the market values that are determined as set forth in subsection (a) to the electric power and energy that would have been used to serve the delivery services customers' electric power and energy requirements, based on the usage specified in Section 16-102 and taking into account the daily, monthly, annual and other relevant characteristics of the customers' demands on the electric utility's system.

(l) In calculating a lump sum transition charge payment for the purposes of subsection (h) of Section 16-108, the electric utility shall use the market values that were determined as provided in its tariff, or if such market values have not been determined for the full period of time covered by such lump sum calculation, such other basis as is stated in the electric utility's tariff filed pursuant to Section 16-108.

(m) The Commission may approve or reject, or propose modifications to, any tariff providing for the determination of market value that has been proposed by an electric utility pursuant to subsection (a) of this Section, but shall not have the power to otherwise order the electric utility to implement a modified tariff or to place into effect any tariff for the determination of market value other than one incorporating the neutral fact-finder procedure set forth in this Section. Provided, however, that if each electric utility serving at least 300,000 customers has placed into effect a tariff that provides for a determination of market value as a function of an exchange traded or other market traded index, options or futures contract or contracts, then the Commission can require any other electric utilities to file such a tariff, and can terminate the neutral fact-finder procedure for the periods covered by such tariffs.

(n) To the extent that the summaries list a sufficient number of actual contracts to represent a viable market and market values can be determined for more than one year, the electric utility shall offer customers that are obligated to pay transition charges contracts that establish for one or more years, up to a maximum of the lesser of 5 years or the remaining number of years until December 31, 2008, the market value or values to be used in calculating the customer's transition charges in such years and for which market value determinations have been made. The electric utility may require any customer to give up to one year notice prior to entering into a one or 2 year contract pursuant to this subsection, up to 2 years notice for a 3 year contract, and up to 3 years notice for a 4 or 5 year contract. Contracts of one or 2 years duration shall incorporate the market values that were determined as provided in this Section in the year in which the notice is required to be given. Contracts of more than 2 years duration shall incorporate the market values that are determined in the year prior to the first year in which the electric utility will collect transition charges from the customer under the contract. The electric utility shall also allow customers to select, at the time that a customer gives its notice, an option to revoke the notice within 30 days following the determination of the market values that will apply under the contract requested by the customer, and may charge customers a fee for such option that is set forth in a tariff filed pursuant to Article IX and that is adequate to allow the electric utility to recover its transactional costs and compensate it based on the cost that would be incurred to purchase an option to cover the risk associated with the customer's option to revoke. The electric utility shall not be required to offer customers a contract under this paragraph for any year for which no determination of market value has been made either by the neutral fact-finder or pursuant to a tariff filed by the electric utility.

(o) An electric utility shall have no obligation to provide electric power or energy as a tariffed service for the electric power and energy requirements placed on delivery service by any customer that has entered into a contract pursuant to subsection (n) of this Section and has not purchased and exercised an option to revoke, during the term of the contract. A customer that has purchased and exercised an option to revoke under this subsection shall remain eligible to receive any tariffed service for which it would otherwise be eligible.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-113)

Sec. 16-113. Declaration of service as a competitive service.

(a) An electric utility may, by petition, request the Commission to declare a tariffed service that is provided by the electric utility, and that has not otherwise been declared to be competitive, to be a competitive service. The electric utility shall give notice of its petition to the public in the same manner that public notice is provided for proposed general increases in rates for tariffed services, in accordance with rules and regulations prescribed by the Commission. The Commission shall hold a hearing and shall declare the class of tariffed service to be a competitive service within the electric utility's service area, only after the electric utility demonstrates that at least 33% of the customers in the electric utility's service area that are eligible to take the class of tariffed service instead take service from alternative retail electric suppliers, as defined in Section 16-102, and that at least 3 alternative retail electric suppliers provide service that is comparable to the class of tariffed service to those customers in the electric utility's service area that do not take service from the electric utility. The Commission shall make its determination and issue its final order declaring or refusing to declare the service to be a competitive service within 180 days following the date that the petition is filed.

(b) Except as otherwise set forth in this Section, any customer except a customer identified in subsection (c) of Section 16-103 who is taking a tariffed service that is declared to be a competitive service pursuant to subsection (a) of this Section shall be entitled to continue to take the service from the electric utility on a tariffed basis for a period of 3 years following the date that the service is declared competitive, or such other period as is stated in the electric utility's tariff pursuant to Section 16-110. This subsection shall not require the electric utility to offer or provide on a tariffed basis any service to any customer (except those customers identified in subsection (c) of Section 16-103) that was not taking such service on a tariffed basis on the date the service was declared to be competitive.

Customers of an electric utility that on December 31, 2005 provided electric service to at least 2,000,000 customers in Illinois and (i) whose service is declared to be a competitive service pursuant to subsection (f) of this Section, (ii) that have peak demand of 400 kilowatts and above, and (iii) that were taking that service from the utility on the effective date of this amendatory Act through fixed-price bundled service tariffs, shall be entitled to continue to take the service from the electric utility on a tariffed basis through the end of the May 2008 billing period. Customers of an electric utility that on December 31, 2005 provided electric service to at least 2,000,000 customers in Illinois and (i) whose service is declared to be a competitive service pursuant to subsection (g) of this Section, (ii) that have peak demand of 100 kilowatts and above but less than 400 kilowatts, and (iii) that were taking that service from the utility on the effective date of this amendatory Act through fixed-price bundled service tariffs, shall be entitled to continue to take the service from the electric utility on a tariffed basis through the end of the May 2010 billing period.

Customers of an electric utility that on December 31, 2005 provided electric service to 2,000,000 or fewer customers but more than 100,000 customers in Illinois and (i) whose service is declared to be a competitive service pursuant to subsection (f) of this Section, (ii) that have peak demand of one megawatt and above, and (iii) that were taking that service from the utility on the effective date of this amendatory Act through fixed-price bundled service tariffs, shall be entitled to continue to take the service from the electric utility on a tariffed basis through the end of May 2008. Customers of an electric utility that on December 31, 2005 provided electric service to 2,000,000 or fewer customers but more than 100,000 customers in the State of Illinois and (i) whose service is declared to be a competitive service pursuant to subsection (f) of this Section, (ii) that have peak demand of 400 kilowatts and above but less than one megawatt, and (iii) that were taking that service from the utility on the effective date of this amendatory Act through fixed-price bundled service tariffs, shall be entitled to continue to take the service from the electric utility on a tariffed basis through the end of May 2010.

(c) If the Commission denies a petition to declare a service to be a competitive service, or determines in a separate proceeding that a service is not competitive based on the criteria set forth in subsection (a), the electric utility may file a new petition no earlier than 6 months following the date of the Commission's order, requesting, on the basis of additional or different facts and circumstances, that the service be declared to be a competitive service.

(d) The Commission shall not deny a petition to declare a service to be a competitive service, and shall not find that a service is not a competitive service, on the grounds that it has previously denied the petition of another electric utility to declare the same or a similar service to be a competitive service or has previously determined that the same or a similar service provided by another electric utility is not a competitive service.

(e) An electric utility may declare a service, other than delivery services or the provision of electric power or energy, to be competitive by filing with the Commission at least 14 days prior to the date on which the service is to become competitive a notice describing the service that is being declared competitive and the date on which it will become competitive; provided, that any customer who is taking a tariffed service that is declared to be a competitive service pursuant to this subsection (e) shall be entitled to continue to take the service from the electric utility on a tariffed basis until the electric utility files, and the Commission grants, a petition to declare the service competitive in accordance with subsection (a) of this Section. The Commission shall be authorized to find and order, after notice and hearing in a subsequent proceeding initiated by the Commission, that any service declared to be competitive pursuant to this subsection (e) is not competitive in accordance with the criteria set forth in subsection (a) of this Section.

(f) As of the effective date of this amendatory Act, the provision of electric power and energy, whether through fixed-price bundled service tariffs or otherwise, to those retail customers with peak demands of 400 kilowatts and above that are served by an electric utility that on December 31, 2005 served more than 100,000 customers in its service territory in Illinois shall be deemed to be, and is declared to be, a competitive service.

(g) An electric utility that provided electric service to at least 100,000 customers in its service territory in Illinois as of December 31, 2005 may seek to declare the provision of electric power and energy, whether through fixed-price bundled service tariffs or otherwise, to those retail customers with peak demand of 100 kilowatts and above but less than 400 kilowatts to be competitive by filing with the Commission at least 60 days prior to the date on which the service is to become competitive a petition with attached analyses demonstrating that at least 33% of those customers in the electric utility's service area that are eligible to take the class of tariffed service instead take service from alternative retail electric suppliers, as defined in Section 16-102, and that at least 3 alternative retail electric suppliers provide service that is comparable to that tariffed service to those customers in the electric utility's service area that do not take service from the electric utility. The electric utility shall give notice of its petition to the public in the same manner that public notice is provided for proposed general increases in rates for tariffed services, in accordance with rules and regulations prescribed by the Commission. Within 14 days following filing of the petition, any person may file a detailed objection with the Commission contesting the analyses submitted by the electric utility with its petition. All objections to the electric utility's petition shall be specific, supported by data or other detailed analyses, and limited to whether the electric utility has met the standard set forth in this subsection (g). The electric utility may file a response to any objections to its petition within 7 days after the deadline for objections. The Commission shall declare the provision of electric power and energy by the electric utility to those retail customers with peak demand of 100 kilowatts and above but less than 400 kilowatts to be a competitive service within 30 days after the filing of the petition if it finds that the electric utility has met the standard set forth in this subsection (g). If, however, the Commission finds that there are material issues of disputed fact, it may require the parties to submit additional information, including through additional filings or as part of an evidentiary hearing. If the Commission has required the parties to submit additional information, it shall issue an order within 60 days after the filing of the petition stating whether the provision of electric power and energy by the utility to those retail customers with peak demand of 100 kilowatts and above but less than 400 kilowatts has been declared to be a competitive service.

(h) Until July 1, 2012, no electric utility that on December 31, 2005 provided electric service to at least 100,000 customers in its service territory in Illinois may seek to declare the class of tariffed service for residential customers and those non-residential customers with peak demand of less than 100 kilowatts to be a competitive service.

(Source: P.A. 95-481, eff. 8-28-07.)

(220 ILCS 5/16-114)

Sec. 16-114. Recovery of decommissioning charges. On or before April 1, 1999, each electric utility owning an interest in, or having responsibility as a matter of contract or statute for decommissioning costs as defined in Section 8-508.1 of, one or more nuclear power plants shall file with the Commission a tariff or tariffs conforming to the provisions of Section 9-201.5 of this Act, to be applicable to each and every kilowatt-hour of electricity delivered or sold at retail in the electric utility's service area, including, but not limited to, sales by the electric utility to tariffed services retail customers, sales by the electric utility to retail customers pursuant to special contracts or other negotiated arrangements, sales by alternative retail electric suppliers, and sales by an electric utility other than the electric utility in whose service area the retail customer is located; provided, however, that for a user that obtained electric power and energy from its own cogeneration or self-generation facilities on or before January 1, 1997, and subsequently takes services from an alternative retail electric supplier or an electric utility other than the electric utility in whose service area the user is located for any portion of its electric power and energy requirements formerly obtained from those facilities, the tariff required by this Section shall not be applicable in any year to that portion of the user's electric power and energy requirements formerly obtained from those facilities, provided that for the purposes of this Section, such portion shall not exceed the average number of kilowatt-hours per year obtained from the cogeneration or self-generation facilities during the 3 years prior to the date on which the user became eligible for delivery services.

The Commission shall determine whether the tariff meets the requirements of Sections 9-201 and 9-201.5 and of this Section, and shall permit the electric utility's tariff together with any modifications made after hearing to become effective no later than October 1, 1999. In making its determination, the Commission shall retain the authority it possessed prior to the effective date of this amendatory Act of 1997 to make jurisdictional allocations of decommissioning expense recovery. The tariff filed pursuant to this Section shall be applicable to any user taking some or all of its electric power and energy requirements from an alternative retail electric supplier or from an electric utility other than the electric utility in whose service area the user is located on and after the date that the user becomes eligible for delivery services in accordance with Section 16-104. If the electric utility has in effect as of the effective date of this amendatory Act of 1997 a decommissioning rate as defined in Section 9-201.5 conforming to the requirements of that Section, the tariff or tariffs required by this Section shall if the electric utility requests be consistent with its decommissioning rate that is already in effect; provided, that the tariff or tariffs filed pursuant to this Section shall provide for the removal from base rates of any decommissioning costs that are included in the electric utility's base rates and their inclusion in the tariff or tariffs required by this Section. The tariff required by this Section shall be included by the Commission in the reviews required by subsection (d) of Section 9-201.5.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-114.1)

Sec. 16-114.1. Recovery of decommissioning costs in connection with nuclear power plant sale agreement.

(a) An electric utility owning a single-unit nuclear power plant located in this State which enters into an agreement to sell the nuclear power plant and as part of such agreement agrees: (i) to make contributions to a tax-qualified decommissioning trust or non-tax qualified decommissioning trust, or both, as defined in Section 8-508.1 for the nuclear power plant, in specified amounts or for a specified period of time, after the sale is consummated, or (ii) to purchase an insurance instrument which provides for the payment of all or a specified amount of the decommissioning costs of the nuclear power plant, shall be entitled, in the case of item (i), to maintain such decommissioning trusts for the purpose of receiving such contributions after the consummation of the sale, to implement revisions to its decommissioning rate in accordance with subsection (b) of this Section, and to transfer such decommissioning trusts, or the balance in the trusts, to the buyer of the nuclear power plant in accordance with the agreement of sale, and in the case of item (ii), to implement revisions to its decommissioning rate in accordance with subsection (c) of this Section.

(b) An electric utility entering into an agreement of sale described in subsection (a)(i) of this Section shall be entitled to file a petition with the Commission for entry of an order authorizing the electric utility (i) to amortize its liability for decommissioning costs pursuant to the agreement of sale over the period of time in which the electric utility is required by such agreement to make additional contributions to the tax-qualified decommissioning trust, the non-tax qualified decommissioning trust, or both, and (ii) to revise its decommissioning rate to a level that will recover, over the time period specified in the agreement of sale, an annual amount equal to the electric utility's annual contributions to the decommissioning trusts which are required by the agreement of sale multiplied by the percentage of the output of the nuclear power plant which the agreement of sale obligates the electric utility to purchase in each such year.

(c) An electric utility entering into an agreement of sale described in subsection (a)(ii) shall be entitled to file a petition with the Commission for entry of an order authorizing the electric utility to revise its decommissioning rate to a level that will recover, over 5 years, the electric utility's cost of purchasing the insurance instrument multiplied by the percentage of the output of the nuclear power plant which the agreement of sale obligates the electric utility to purchase in each such year.

(d) An electric utility's petition pursuant to subsection (b) or subsection (c) shall state the percentage of the output of the nuclear power plant which the agreement of sale obligates the electric utility to purchase from the new owner of the nuclear power plant in each of the years for which the electric utility is seeking to implement a revised decommissioning rate. The electric utility's petition shall also state that the electric utility agrees, as conditions of the Commission's order and the implementation of the revised decommissioning rate, (i) to file revisions, pursuant to Section 16-111(f), to its base rate tariffs applicable to retail customers subject to the electric utility's decommissioning rate reducing such tariffs, and (ii) to file revisions to its transition charge tariffs applicable to retail customers subject to the electric utility's decommissioning rate incorporating a credit into the calculation of the electric utility's transition charges in accordance with this subsection. The reduction and the credit shall be in an amount per kilowatt-hour of electricity sold or delivered to retail customers equal to (i) the electric utility's decommissioning rate authorized by the Commission's order in accordance with subsection (b)(ii) or (c), as applicable, less (ii) the product of the electric utility's decommissioning rate in effect immediately prior to the agreement of sale multiplied by the percentage of the output of the nuclear power plant which the agreement of sale obligates the electric utility to purchase from the new owner of the nuclear power plant. The Commission shall issue an order granting the petition within 30 days after the petition is filed. The Commission's order shall state the aggregate total amount which the order is authorizing the electric utility to collect through its decommissioning rate. The Commission's order shall state that the effectiveness of the revisions to the electric utility's decommissioning rate shall be conditioned on the filing by the electric utility of the revisions reducing its base rate tariffs and providing for credits to its transition charge tariffs as specified in this subsection. Upon completion of the collection of the total amount which the Commission's order authorizes the electric utility to collect through its decommissioning rate, the electric utility shall not be entitled to collect any further amounts of decommissioning costs for its nuclear power plant through a decommissioning rate. Nothing in this Section shall be construed to permit an increase in the overall tariffed rates and charges paid by the electric utility's customers.

(e) In addition to the uses of the proceeds of the sale and issuance of transitional funding instruments authorized by Section 18-103(d)(1), an electric utility which has entered into an agreement to sell a nuclear power plant may use the proceeds from the sale and issuance of transitional funding instruments to make contributions, or to reimburse itself for contributions which the electric utility has made, to decommissioning trusts in accordance with the agreement of sale, in an amount not to exceed 20% of the aggregate principal amount of transitional funding instruments which the electric utility was authorized to cause to have issued pursuant to Section 18-103(d)(6), including for purposes of this calculation the amount of any transitional funding instruments which the electric utility caused to be issued prior to the date of this amendatory Act of 1999. The use of proceeds authorized by this subsection shall not be subject to Section 18-103(d)(1)(B) and shall not be considered in determining if the percentage limitations on the use of proceeds set forth in the proviso following Section 18-103(d)(1)(E) have been complied with.

(f) None of the authorizations permitted by this Section may be exercised if the sale of the nuclear power plant is disapproved by the Commission.

(Source: P.A. 91-50, eff. 6-30-99.)

(220 ILCS 5/16-115)

Sec. 16-115. Certification of alternative retail electric suppliers.

(a) Any alternative retail electric supplier must obtain a certificate of service authority from the Commission in accordance with this Section before serving any retail customer or other user located in this State. An alternative retail electric supplier may request, and the Commission may grant, a certificate of service authority for the entire State or for a specified geographic area of the State. A certificate granted pursuant to this Section is not property, and the grant of a certificate to an entity does not create a property interest in the certificate. This Section does not diminish the existing rights of a certificate holder to notice and hearing as proscribed by the Illinois Administrative Procedure Act and in rules adopted by the Commission.

(b) An alternative retail electric supplier seeking a certificate of service authority shall file with the Commission a verified application containing information showing that the applicant meets the requirements of this Section. The alternative retail electric supplier shall publish notice of its application in the official State newspaper within 10 days following the date of its filing. No later than 45 days after a complete application is properly filed with the Commission, and such notice is published, the Commission shall issue its order granting or denying the application.

(c) An application for a certificate of service authority shall identify the area or areas in which the applicant intends to offer service and the types of services it intends to offer. Applicants that seek to serve residential or small commercial retail customers within a geographic area that is smaller than an electric utility's service area shall submit evidence demonstrating that the designation of this smaller area does not violate Section 16-115A. An applicant that seeks to serve residential or small commercial retail customers may state in its application for certification any limitations that will be imposed on the number of customers or maximum load to be served.

(d) The Commission shall grant the application for a certificate of service authority if it makes the findings set forth in this subsection based on the verified application and such other information as the applicant may submit:

(1) That the applicant possesses sufficient technical, financial, and managerial resources and abilities to provide the service for which it seeks a certificate of service authority. In determining the level of technical, financial, and managerial resources and abilities which the applicant must demonstrate, the Commission shall consider (i) the characteristics, including the size and financial sophistication, of the customers that the applicant seeks to serve, and (ii) whether the applicant seeks to provide electric power and energy using property, plant, and equipment which it owns, controls, or operates;

(2) That the applicant will comply with all applicable federal, State, regional, and industry rules, policies, practices, and procedures for the use, operation, and maintenance of the safety, integrity, and reliability, of the interconnected electric transmission system;

(3) That the applicant will only provide service to retail customers in an electric utility's service area that are eligible to take delivery services under this Act;

(4) That the applicant will comply with such informational or reporting requirements as the Commission may by rule establish and provide the information required by Section 16-112. Any data related to contracts for the purchase and sale of electric power and energy shall be made available for review by the Staff of the Commission on a confidential and proprietary basis and only to the extent and for the purposes which the Commission determines are reasonably necessary in order to carry out the purposes of this Act;

(5) That the applicant will procure renewable energy resources in accordance with Section 16-115D of this Act, and will source electricity from clean coal facilities, as defined in Section 1-10 of the Illinois Power Agency Act, in amounts at least equal to the percentages set forth in subsections (c) and (d) of Section 1-75 of the Illinois Power Agency Act. For purposes of this Section:

(i) (blank);

(ii) (blank);

(iii) the required sourcing of electricity generated by clean coal facilities, other than the initial clean coal facility, shall be limited to the amount of electricity that can be procured or sourced at a price at or below the benchmarks approved by the Commission each year in accordance with item (1) of subsection (c) and items (1) and (5) of subsection (d) of Section 1-75 of the Illinois Power Agency Act;

(iv) all alternative retail electric suppliers shall execute a sourcing agreement to source electricity from the initial clean coal facility, on the terms set forth in paragraphs (3) and (4) of subsection (d) of Section 1-75 of the Illinois Power Agency Act, except that in lieu of the requirements in subparagraphs (A)(v), (B)(i), (C)(v), and (C)(vi) of paragraph (3) of that subsection (d), the applicant shall execute one or more of the following:

(1) if the sourcing agreement is a power purchase agreement, a contract with the initial clean coal facility to purchase in each hour an amount of electricity equal to all clean coal energy made available from the initial clean coal facility during such hour, which the utilities are not required to procure under the terms of subsection (d) of Section 1-75 of the Illinois Power Agency Act, multiplied by a fraction, the numerator of which is the alternative retail electric supplier's retail market sales of electricity (expressed in kilowatthours sold) in the State during the prior calendar month and the denominator of which is the total sales of electricity (expressed in kilowatthours sold) in the State by alternative retail electric suppliers during such prior month that are subject to the requirements of this paragraph (5) of subsection (d) of this Section and subsection (d) of Section 1-75 of the Illinois Power Agency Act plus the total sales of electricity (expressed in kilowatthours sold) by utilities outside of their service areas during such prior month, pursuant to subsection (c) of Section 16-116 of this Act; or

(2) if the sourcing agreement is a contract for differences, a contract with the initial clean coal facility in each hour with respect to an amount of electricity equal to all clean coal energy made available from the initial clean coal facility during such hour, which the utilities are not required to procure under the terms of subsection (d) of Section 1-75 of the Illinois Power Agency Act, multiplied by a fraction, the numerator of which is the alternative retail electric supplier's retail market sales of electricity (expressed in kilowatthours sold) in the State during the prior calendar month and the denominator of which is the total sales of electricity (expressed in kilowatthours sold) in the State by alternative retail electric suppliers during such prior month that are subject to the requirements of this paragraph (5) of subsection (d) of this Section and subsection (d) of Section 1-75 of the Illinois Power Agency Act plus the total sales of electricity (expressed in kilowatthours sold) by utilities outside of their service areas during such prior month, pursuant to subsection (c) of Section 16-116 of this Act;

(v) if, in any year after the first year of commercial operation, the owner of the clean coal facility fails to demonstrate to the Commission that the initial clean coal facility captured and sequestered at least 50% of the total carbon emissions that the facility would otherwise emit or that sequestration of emissions from prior years has failed, resulting in the release of carbon into the atmosphere, the owner of the facility must offset excess emissions. Any such carbon offsets must be permanent, additional, verifiable, real, located within the State of Illinois, and legally and practicably enforceable. The costs of any such offsets that are not recoverable shall not exceed $15,000,000 in any given year. No costs of any such purchases of carbon offsets may be recovered from an alternative retail electric supplier or its customers. All carbon offsets purchased for this purpose and any carbon emission credits associated with sequestration of carbon from the facility must be permanently retired. The initial clean coal facility shall not forfeit its designation as a clean coal facility if the facility fails to fully comply with the applicable carbon sequestration requirements in any given year, provided the requisite offsets are purchased. However, the Attorney General, on behalf of the People of the State of Illinois, may specifically enforce the facility's sequestration requirement and the other terms of this contract provision. Compliance with the sequestration requirements and offset purchase requirements that apply to the initial clean coal facility shall be reviewed annually by an independent expert retained by the owner of the initial clean coal facility, with the advance written approval of the Attorney General;

(vi) The Commission shall, after notice and hearing, revoke the certification of any alternative retail electric supplier that fails to execute a sourcing agreement with the initial clean coal facility as required by item (5) of subsection (d) of this Section. The sourcing agreements with this initial clean coal facility shall be subject to both approval of the initial clean coal facility by the General Assembly and satisfaction of the requirements of item (4) of subsection (d) of Section 1-75 of the Illinois Power Agency Act, and shall be executed within 90 days after any such approval by the General Assembly. The Commission shall not accept an application for certification from an alternative retail electric supplier that has lost certification under this subsection (d), or any corporate affiliate thereof, for at least one year from the date of revocation;

(6) With respect to an applicant that seeks to serve residential or small commercial retail customers, that the area to be served by the applicant and any limitations it proposes on the number of customers or maximum amount of load to be served meet the provisions of Section 16-115A, provided, that the Commission can extend the time for considering such a certificate request by up to 90 days, and can schedule hearings on such a request;

(7) That the applicant meets the requirements of subsection (a) of Section 16-128;

(8) That the applicant discloses whether the applicant is the subject of any lawsuit filed in a court of law or formal complaint filed with a regulatory agency alleging fraud, deception, or unfair marketing practices or other similar allegations and, if the applicant is the subject of such lawsuit or formal complaint, the applicant shall identify the name, case number, and jurisdiction of each lawsuit or complaint, and that the applicant is capable of fulfilling its obligations as an alternative retail electric supplier in Illinois notwithstanding any lawsuit or complaint. For the purpose of this item (8), "formal complaint" includes only those complaints that seek a binding determination from a State or federal regulatory body;

(9) That the applicant shall at all times remain in compliance with requirements for certification stated in this Section and as the Commission may establish by rule;

(10) That the applicant shall execute and maintain a license or permit bond issued by a qualifying surety or insurance company authorized to transact business in the State of Illinois in favor of the People of the State of Illinois. The amount of the bond shall equal $30,000 if the applicant seeks to serve only nonresidential retail customers with maximum electrical demands of one megawatt or more, $150,000 if the applicant seeks to serve only nonresidential retail customers with annual electrical consumption greater than 15,000 kilowatt-hours, or $500,000 if the applicant seeks to serve all eligible customers. Applicants shall be required to submit an additional $500,000 bond if the applicant intends to market to residential customers using in-person solicitations. The bonds shall be conditioned upon the full and faithful performance of all duties and obligations of the applicant as an alternative retail electric supplier, shall be valid for a period of not less than one year, and may be drawn upon in whole or in part to satisfy any penalties imposed, and finally adjudicated, by the Commission pursuant to Section 16-115B for a violation of the applicant's duties or obligations, except that the total amount of claims and penalties against the bond shall not exceed the penal sum of the bond and shall not include any consequential or punitive damage. The cost of the bond shall be paid by the applicant. The applicant shall file a copy of this bond, with a notarized verification page from the issuer, as part of its application for certification under 83 Ill. Adm. Code 451; and

(11) That the applicant will comply with all other applicable laws and regulations.

(d-3) The Commission may deny with prejudice an application in which the applicant fails to provide the Commission with information sufficient for the Commission to grant the application.

(d-5) (Blank).

(e) A retail customer that owns a cogeneration or self-generation facility and that seeks certification only to provide electric power and energy from such facility to retail customers at separate locations which customers are both (i) owned by, or a subsidiary or other corporate affiliate of, such applicant and (ii) eligible for delivery services, shall be granted a certificate of service authority upon filing an application and notifying the Commission that it has entered into an agreement with the relevant electric utilities pursuant to Section 16-118. Provided, however, that if the retail customer owning such cogeneration or self-generation facility would not be charged a transition charge due to the exemption provided under subsection (f) of Section 16-108 prior to the certification, and the retail customers at separate locations are taking delivery services in conjunction with purchasing power and energy from the facility, the retail customer on whose premises the facility is located shall not thereafter be required to pay transition charges on the power and energy that such retail customer takes from the facility.

(f) The Commission shall have the authority to promulgate rules and regulations to carry out the provisions of this Section. On or before May 1, 1999, the Commission shall adopt a rule or rules applicable to the certification of those alternative retail electric suppliers that seek to serve only nonresidential retail customers with maximum electrical demands of one megawatt or more which shall provide for (i) expedited and streamlined procedures for certification of such alternative retail electric suppliers and (ii) specific criteria which, if met by any such alternative retail electric supplier, shall constitute the demonstration of technical, financial and managerial resources and abilities to provide service required by paragraph (1) of subsection (d) of this Section, such as a requirement to post a bond or letter of credit, from a responsible surety or financial institution, of sufficient size for the nature and scope of the services to be provided; demonstration of adequate insurance for the scope and nature of the services to be provided; and experience in providing similar services in other jurisdictions.

(g) An alternative retail electric supplier may seek confidential treatment for the following information by filing an affidavit with the Commission so long as the affidavit meets the requirements in this subsection (g):

(1) the total annual kilowatt-hours delivered and sold by an alternative retail electric supplier to retail customers within each utility service territory and the total annual kilowatt-hours delivered and sold by an alternative retail electric supplier to retail customers in all utility service territories in the preceding calendar year as required by 83 Ill. Adm. Code 451.770;

(2) the total peak demand supplied by an alternative retail electric supplier during the previous year in each utility service territory as required by 83 Ill. Adm. Code 465.40;

(3) a good faith estimate of the amount an alternative retail electric supplier expects to be obliged to pay the utility under single billing tariffs during the next 12 months and the amount of any bond or letter of credit used to demonstrate an alternative retail electric supplier's credit worthiness to provide single billing services pursuant to 83 Ill. Adm. Code 451.510(a) and (b).

The affidavit must be filed contemporaneously with the information for which confidential treatment is sought and must clearly state that the affiant seeks confidential treatment pursuant to this subsection (g) and the information for which confidential treatment is sought must be clearly identified on the confidential version of the document filed with the Commission. The affidavit must be accompanied by a "confidential" and a "public" version of the document or documents containing the information for which confidential treatment is sought.

If the alternative retail electric supplier has met the affidavit requirements of this subsection (g), then the Commission shall afford confidential treatment to the information identified in the affidavit for a period of 2 years after the date the affidavit is received by the Commission.

Nothing in this subsection (g) prevents an alternative retail electric supplier from filing a petition with the Commission seeking confidential treatment for information beyond that identified in this subsection (g) or for information contained in other reports or documents filed with the Commission other than annual rate reports.

Nothing in this subsection (g) prevents the Commission, on its own motion, or any party from filing a formal petition with the Commission seeking to reconsider the conferring of confidential status on an item of information afforded confidential treatment pursuant to this subsection (g).

The Commission, on its own motion, may at any time initiate a docketed proceeding to investigate the continued applicability of this subsection (g) to the information contained in items (i), (ii), and (iii) of this subsection (g). If, at the end of such investigation, the Commission determines that a particular item of information should no longer be eligible for the affidavit-based process outlined in this subsection (g), the Commission may enter an order to remove that item from the list of items eligible for the process set forth in this subsection (g). Notwithstanding any such order, in the event the Commission makes such a determination, nothing in this subsection (g) prevents an alternative retail electric supplier desiring confidential treatment for such information from filing a formal petition with the Commission seeking confidential treatment for such information.

(Source: P.A. 101-590, eff. 1-1-20; 102-958, eff. 1-1-23.)

(220 ILCS 5/16-115A)

Sec. 16-115A. Obligations of alternative retail electric suppliers.

(a) An alternative retail electric supplier:

(i) shall comply with the requirements imposed on public utilities by Sections 8-201 through 8-207, 8-301, 8-505 and 8-507 of this Act, to the extent that these Sections have application to the services being offered by the alternative retail electric supplier;

(ii) shall continue to comply with the requirements for certification stated in subsection (d) of Section 16-115;

(iii) by May 31, 2020 and every June 30 thereafter, shall submit to the Commission and the Office of the Attorney General the rates the retail electric supplier charged to residential customers in the prior year, including each distinct rate charged and whether the rate was a fixed or variable rate, the basis for the variable rate, and any fees charged in addition to the supply rate, including monthly fees, flat fees, or other service charges; and

(iv) shall make publicly available on its website, without the need for a customer login, rate information for all of its variable, time-of-use, and fixed rate contracts currently available to residential customers, including, but not limited to, fixed monthly charges, early termination fees, and kilowatt-hour charges.

(b) An alternative retail electric supplier shall obtain verifiable authorization from a customer, in a form or manner approved by the Commission consistent with Section 2EE of the Consumer Fraud and Deceptive Business Practices Act, before the customer is switched from another supplier.

(c) No alternative retail electric supplier, or electric utility other than the electric utility in whose service area a customer is located, shall (i) enter into or employ any arrangements which have the effect of preventing a retail customer with a maximum electrical demand of less than one megawatt from having access to the services of the electric utility in whose service area the customer is located or (ii) charge retail customers for such access. This subsection shall not be construed to prevent an arms-length agreement between a supplier and a retail customer that sets a term of service, notice period for terminating service and provisions governing early termination through a tariff or contract as allowed by Section 16-119.

(d) An alternative retail electric supplier that is certified to serve residential or small commercial retail customers shall not:

(1) deny service to a customer or group of customers nor establish any differences as to prices, terms, conditions, services, products, facilities, or in any other respect, whereby such denial or differences are based upon race, gender or income, except as provided in Section 16-115E.

(2) deny service to a customer or group of customers based on locality nor establish any unreasonable difference as to prices, terms, conditions, services, products, or facilities as between localities.

(3) warrant that it has a residential customer or small commercial retail customer's express consent agreement to access interval data as described in subsection (b) of Section 16-122, unless the alternative retail electric supplier has:

(A) disclosed to the consumer at the outset of the offer that the alternative retail electric supplier will access the consumer's interval data from the consumer's utility with the consumer's express agreement and the consumer's option to refuse to provide express agreement to access the consumer's interval data; and

(B) obtained the consumer's express agreement for the alternative retail electric supplier to access the consumer's interval data from the consumer's utility in a separate letter of agency, a distinct response to a third-party verification, or as a separate affirmative consent during a recorded enrollment initiated by the consumer. The disclosure by the alternative retail electric supplier to the consumer in this Section shall be conducted in, translated into, and provided in a language in which the consumer subject to the disclosure is able to understand and communicate.

(4) release, sell, license, or otherwise disclose any customer interval data obtained under Section 16-122 to any third person except as provided for in Section 16-122 and paragraphs (1) through (4) of subsection (d-5) of Section 2EE of the Consumer Fraud and Deceptive Business Practices Act.

(e) An alternative retail electric supplier shall comply with the following requirements with respect to the marketing, offering and provision of products or services to residential and small commercial retail customers:

(i) All marketing materials, including, but not limited to, electronic marketing materials, in-person solicitations, and telephone solicitations, shall contain information that adequately discloses the prices, terms, and conditions of the products or services that the alternative retail electric supplier is offering or selling to the customer and shall disclose the current utility electric supply price to compare applicable at the time the alternative retail electric supplier is offering or selling the products or services to the customer and shall disclose the date on which the utility electric supply price to compare became effective and the date on which it will expire. The utility electric supply price to compare shall be the sum of the electric supply charge and the transmission services charge and shall not include the purchased electricity adjustment. The disclosure shall include a statement that the price to compare does not include the purchased electricity adjustment, and, if applicable, the range of the purchased electricity adjustment. All marketing materials, including, but not limited to, electronic marketing materials, in-person solicitations, and telephone solicitations, shall include the following statement:

"(Name of the alternative retail electric supplier) is not the same entity as your electric delivery company. You are not required to enroll with (name of alternative retail electric supplier). Beginning on (effective date), the electric supply price to compare is (price in cents per kilowatt hour). The electric utility electric supply price will expire on (expiration date). The utility electric supply price to compare does not include the purchased electricity adjustment factor. For more information go to the Illinois Commerce Commission's free website at www.pluginillinois.org.".

If applicable, the statement shall also include the following statement:

"The purchased electricity adjustment factor may range between +.5 cents and -.5 cents per kilowatt hour.".

This paragraph (i) does not apply to goodwill or institutional advertising.

(ii) Before any customer is switched from another supplier, the alternative retail electric supplier shall give the customer written information that adequately discloses, in plain language, the prices, terms and conditions of the products and services being offered and sold to the customer. This written information shall be provided in a language in which the customer subject to the marketing or solicitation is able to understand and communicate, and the alternative retail electric supplier shall not switch a customer who is unable to understand and communicate in a language in which the marketing or solicitation was conducted. The alternative retail electric supplier shall comply with Section 2N of the Consumer Fraud and Deceptive Business Practices Act.

(iii) An alternative retail electric supplier shall provide documentation to the Commission and to customers that substantiates any claims made by the alternative retail electric supplier regarding the technologies and fuel types used to generate the electricity offered or sold to customers.

(iv) The alternative retail electric supplier shall provide to the customer (1) itemized billing statements that describe the products and services provided to the customer and their prices, and (2) an additional statement, at least annually, that adequately discloses the average monthly prices, and the terms and conditions, of the products and services sold to the customer.

(v) All in-person and telephone solicitations shall be conducted in, translated into, and provided in a language in which the consumer subject to the marketing or solicitation is able to understand and communicate. An alternative retail electric supplier shall terminate a solicitation if the consumer subject to the marketing or communication is unable to understand and communicate in the language in which the marketing or solicitation is being conducted. An alternative retail electric supplier shall comply with Section 2N of the Consumer Fraud and Deceptive Business Practices Act.

(vi) Each alternative retail electric supplier shall conduct training for individual representatives engaged in in-person solicitation and telemarketing to residential customers on behalf of that alternative retail electric supplier prior to conducting any such solicitations on the alternative retail electric supplier's behalf. Each alternative retail electric supplier shall submit a copy of its training material to the Commission on an annual basis and the Commission shall have the right to review and require updates to the material. After initial training, each alternative retail electric supplier shall be required to conduct refresher training for its individual representatives every 6 months.

(f) An alternative retail electric supplier may limit the overall size or availability of a service offering by specifying one or more of the following: a maximum number of customers, maximum amount of electric load to be served, time period during which the offering will be available, or other comparable limitation, but not including the geographic locations of customers within the area which the alternative retail electric supplier is certificated to serve. The alternative retail electric supplier shall file the terms and conditions of such service offering including the applicable limitations with the Commission prior to making the service offering available to customers.

(g) Nothing in this Section shall be construed as preventing an alternative retail electric supplier, which is an affiliate of, or which contracts with, (i) an industry or trade organization or association, (ii) a membership organization or association that exists for a purpose other than the purchase of electricity, or (iii) another organization that meets criteria established in a rule adopted by the Commission, from offering through the organization or association services at prices, terms and conditions that are available solely to the members of the organization or association.

(Source: P.A. 102-459, eff. 8-20-21; 103-237, eff. 6-30-23.)

(220 ILCS 5/16-115B)

Sec. 16-115B. Commission oversight of services provided by alternative retail electric suppliers.

(a) The Commission shall have jurisdiction in accordance with the provisions of Article X of this Act to entertain and dispose of any complaint made by the Commission, on its own motion, or by any person or corporation, chamber of commerce, board of trade, or any industrial, commercial, mercantile, agricultural or manufacturing society, or any body politic or municipal corporation against any alternative retail electric supplier alleging (i) that the alternative retail electric supplier has violated or is in nonconformance with any applicable provisions of Section 16-115 through Section 16-115A; (ii) that the alternative retail electric supplier violated rules adopted by the Commission to govern the sales, marketing, or operations of retail electric suppliers; (iii) that an alternative retail electric supplier serving any residential and small commercial customers failed to provide service in accordance with the terms of its contract or contracts with such customer or customers; (iv) that the alternative retail electric supplier has violated or is in nonconformance with the delivery services tariff of, or any of its agreements relating to delivery services with, the electric utility, municipal system, or electric cooperative providing delivery services; or (v) that the alternative retail electric supplier has violated or failed to comply with the requirements of Sections 8-201 through 8-207, 8-301, 8-505, or 8-507 of this Act as made applicable to alternative retail electric suppliers.

(b) The Commission shall have authority, after such administrative notice as is required by the Illinois Administrative Procedure Act and after an administrative hearing held on complaint or on the Commission's own motion:

(1) To order an alternative retail electric supplier to cease and desist, or correct, any violation of or nonconformance with the provisions of Section 16-115 or 16-115A or any violation or nonconformance over which the Commission has jurisdiction under subsection (a) of Section 16-115B;

(2) To impose financial penalties for violations of or nonconformances with the provisions of Section 16-115 or 16-115A, not to exceed $10,000 per occurrence, and for any violations or nonconformances that continue after the Commission issues a cease and desist order, up to an additional $30,000 for each day the violations or nonconformances continue; and

(3) To alter, modify, revoke, or suspend the certificate of service authority of an alternative retail electric supplier for substantial or repeated violations of or nonconformances with the provisions of Section 16-115 or 16-115A.

(c) In addition to other powers and authority granted to it under this Act, the Commission may require an alternative retail electric supplier to enter into a compliance plan. If the Commission comes into possession of information causing it to conclude that an alternative retail electric supplier is violating this Act or the Commission's rules, the Commission may, after notice and hearing, enter an order directing the alternative retail electric supplier to implement practices, procedures, oversight, or other measures or refrain from practices, conduct, or activities that the Commission finds is necessary or reasonable to ensure the alternative retail electric supplier's compliance with this Act and the Commission's rules. Failure by an alternative retail electric supplier to implement or comply with a Commission-ordered compliance plan is a violation of this Section. The Commission, in its discretion, may order a compliance plan under such circumstances as it considers warranted and is not required to order a compliance plan prior to taking other enforcement action against an alternative retail electric supplier. Nothing in this subsection (c) shall be interpreted to limit the authority or right of the Attorney General.

(Source: P.A. 101-590, eff. 1-1-20; 102-958, eff. 1-1-23.)

(220 ILCS 5/16-115C)

Sec. 16-115C. Licensure of agents, brokers, and consultants engaged in the procurement or sale of retail electricity supply for third parties.

(a) The purpose of this Section is to adopt licensing and code of conduct rules in a competitive retail electricity market to protect Illinois consumers from unfair or deceptive acts or practices and to provide persons acting as agents, brokers, and consultants engaged in the procurement or sale of retail electricity supply for third parties with notice of the illegality of those acts or practices.

(a-5) All third-party sales representatives engaged in the marketing of retail electricity supply must, prior to the customer signing a contract, disclose that they are not employed by the electric utility operating in the applicable service territory.

(b) For purposes of this Section, "agents, brokers, and consultants engaged in the procurement or sale of retail electricity supply for third parties" means any person or entity that attempts to procure on behalf of or sell retail electric service to an electric customer in the State. "Agents, brokers, and consultants engaged in the procurement or sale of retail electricity supply for third parties" does not include the Illinois Power Agency or any of its employees, any entity licensed as an alternative retail electric supplier pursuant to 83 Ill. Adm. Code 451 offering retail electric service on its own behalf, any person acting exclusively on behalf of a single alternative retail electric supplier on condition that exclusivity is disclosed to any third party contracted in such agent capacity, any person acting exclusively on behalf of a retail electric supplier on condition that exclusivity is disclosed to any third party contracted in such agent capacity, any person or entity representing a municipal power agency, as defined in Section 11-119.1-3 of the Illinois Municipal Code, or any person or entity that is attempting to procure on behalf of or sell retail electric service to a third party that has aggregate billing demand of all of its affiliated electric service accounts in Illinois of greater than 1,500 kilowatts.

(c) No person or entity shall act as an agent, broker, or consultant engaged in the procurement or sale of retail electricity supply for third parties unless that person or entity is licensed by the Commission under this Section or is offering services on their own behalf under 83 Ill. Adm. Code 451. A license granted pursuant to this Section is not property, and the grant of a license to an entity does not create a property interest in the license.

(d) The Commission shall create requirements for licensure as an agent, broker, or consultant engaged in the procurement or sale of retail electricity supply for third parties, which shall include all of the following criteria:

(1) Technical competence.

(2) Managerial competence.

(3) Financial responsibility, including the posting of an appropriate performance bond.

(4) Annual reporting requirements.

(e) Any person or entity required to be licensed under this Section must:

(1) disclose in plain language in writing to all persons it solicits (i) before July 1, 2011, the total anticipated remuneration to be paid to it by any third party over the period of the proposed underlying customer contract and (ii) on or after July 1, 2011, the total price per kilowatt-hour, and the total anticipated cost, inclusive of all fees or commissions received by the licensee, to be paid by the customer over the period of the proposed underlying customer contract;

(2) disclose, if applicable, to all customers, prior to the customer signing a contract, the fact that they will be receiving compensation from the supplier;

(3) not hold itself out as independent or unaffiliated with any supplier, or both, or use words reasonably calculated to give that impression, unless the person offering service under this Section has no contractual relationship with any retail electricity supplier or its affiliates regarding retail electric service in Illinois;

(4) not utilize false, misleading, materially inaccurate, defamatory, or otherwise deceptive language or materials in the soliciting or providing of its services;

(5) maintain copies of all marketing materials disseminated to third parties for a period of not less than 3 years;

(6) not present electricity pricing information in a manner that favors one supplier over another, unless a valid pricing comparison is made utilizing all relevant costs and terms; and

(7) comply with the requirements of Sections 2EE, 2FF, 2GG, and 2HH of the Consumer Fraud and Deceptive Business Practices Act.

(f) Any person or entity licensed under this Section shall file with the Commission all of the following information no later than March of each year:

(1) A verified report detailing any and all contractual relationships that it has with certified electricity suppliers in the State regarding retail electric service in Illinois.

(2) A verified report detailing the distribution of its customers with the various certified electricity suppliers in Illinois during the prior calendar year. A report under this Section shall not be required to contain customer-identifying information.

A public redacted version of the verified report may be submitted to the Commission along with a proprietary version. The public redacted version may redact from the verified report the name or names of every certified electricity supplier contained in the report to protect against disclosure of competitively sensitive market share information. The information shall be afforded proprietary treatment for 2 years after the date of the filing of the verified report.

(3) A verified statement of any changes to the original licensure qualifications and notice of continuing compliance with all requirements.

(g) The Commission shall have jurisdiction over complaints, including on the Commission's own motion, for violations of this Section. The findings of a violation of this Section by the Commission shall result in discipline on a progressive scale. For a first violation, the Commission may, in its discretion, suspend the license of the person or entity for a period of no less than one month. For a second violation within a 5-year period, the Commission shall suspend the license of the person or entity for a period of not less than 6 months. For a third or subsequent violation within a 5-year period, the Commission shall suspend the license of the disciplined person for a period of not less than 2 years. Notwithstanding the minimum progressive suspensions, the Commission shall have authority, in its discretion, to impose whatever reasonable disciplinary measures it deems appropriate for any violation, including, but not limited to, terminating the license of the person or entity.

(h) This Section shall not apply to a retail customer that operates or manages either directly or indirectly any facilities, equipment, or property used or contemplated to be used to distribute electric power or energy if that retail customer is a political subdivision or public institution of higher education of this State, or any corporation, company, limited liability company, association, joint-stock company or association, firm, partnership, or individual, or their lessees, trusts, or receivers appointed by any court whatsoever that are owned or controlled by the political subdivision, public institution of higher education, or operated by any of its lessees or operating agents.

(Source: P.A. 102-958, eff. 1-1-23.)

(220 ILCS 5/16-115D)

Sec. 16-115D. Renewable portfolio standard for alternative retail electric suppliers and electric utilities operating outside their service territories.

(a) An alternative retail electric supplier shall be responsible for procuring cost-effective renewable energy resources as required under item (5) of subsection (d) of Section 16-115 of this Act as outlined herein:

(1) The definition of renewable energy resources contained in Section 1-10 of the Illinois Power Agency Act applies to all renewable energy resources required to be procured by alternative retail electric suppliers.

(2) Through May 31, 2017, the quantity of renewable energy resources shall be measured as a percentage of the actual amount of metered electricity (megawatt-hours) delivered by the alternative retail electric supplier to Illinois retail customers during the 12-month period June 1 through May 31, commencing June 1, 2009, and the comparable 12-month period in each year thereafter except as provided in item (6) of this subsection (a).

(3) Through May 31, 2017, the quantity of renewable energy resources shall be in amounts at least equal to the annual percentages set forth in item (1) of subsection (c) of Section 1-75 of the Illinois Power Agency Act. At least 60% of the renewable energy resources procured pursuant to items (1) and (3) of subsection (b) of this Section shall come from wind generation and, starting June 1, 2015, at least 6% of the renewable energy resources procured pursuant to items (1) and (3) of subsection (b) of this Section shall come from solar photovoltaics. If, in any given year, an alternative retail electric supplier does not purchase at least these levels of renewable energy resources, then the alternative retail electric supplier shall make alternative compliance payments, as described in subsection (d) of this Section.

(3.5) For the delivery year commencing June 1, 2017, the quantity of renewable energy resources shall be at least 13.0% of the uncovered amount of metered electricity (megawatt-hours) delivered by the alternative retail electric supplier to Illinois retail customers during the delivery year, which uncovered amount shall equal 50% of such metered electricity delivered by the alternative retail electric supplier. For the delivery year commencing June 1, 2018, the quantity of renewable energy resources shall be at least 14.5% of the uncovered amount of metered electricity (megawatt-hours) delivered by the alternative retail electric supplier to Illinois retail customers during the delivery year, which uncovered amount shall equal 25% of such metered electricity delivered by the alternative retail electric supplier. At least 32% of the renewable energy resources procured by the alternative retail electric supplier for its uncovered portion under this paragraph (3.5) shall come from wind or photovoltaic generation. The renewable energy resources procured under this paragraph (3.5) shall not include any resources from a facility whose costs were being recovered through rates regulated by any state or states on or after January 1, 2017.

(4) The quantity and source of renewable energy resources shall be independently verified through the PJM Environmental Information System Generation Attribute Tracking System (PJM-GATS) or the Midwest Renewable Energy Tracking System (M-RETS), which shall document the location of generation, resource type, month, and year of generation for all qualifying renewable energy resources that an alternative retail electric supplier uses to comply with this Section. No later than June 1, 2009, the Illinois Power Agency shall provide PJM-GATS, M-RETS, and alternative retail electric suppliers with all information necessary to identify resources located in Illinois, within states that adjoin Illinois or within portions of the PJM and MISO footprint in the United States that qualify under the definition of renewable energy resources in Section 1-10 of the Illinois Power Agency Act for compliance with this Section 16-115D. Alternative retail electric suppliers shall not be subject to the requirements in item (3) of subsection (c) of Section 1-75 of the Illinois Power Agency Act.

(5) All renewable energy credits used to comply with this Section shall be permanently retired.

(6) The required procurement of renewable energy resources by an alternative retail electric supplier shall apply to all metered electricity delivered to Illinois retail customers by the alternative retail electric supplier pursuant to contracts executed or extended after March 15, 2009.

(b) Compliance obligations.

(1) Through May 31, 2017, an alternative retail electric supplier shall comply with the renewable energy portfolio standards by making an alternative compliance payment, as described in subsection (d) of this Section, to cover at least one-half of the alternative retail electric supplier's compliance obligation for the period prior to June 1, 2017.

(2) For the delivery years beginning June 1, 2017 and June 1, 2018, an alternative retail electric supplier need not make any alternative compliance payment to meet any portion of its compliance obligation, as set forth in paragraph (3.5) of subsection (a) of this Section.

(3) An alternative retail electric supplier shall use any one or combination of the following means to cover the remainder of the alternative retail electric supplier's compliance obligation, as set forth in paragraphs (3) and (3.5) of subsection (a) of this Section, not covered by an alternative compliance payment made under paragraphs (1) and (2) of this subsection (b) of this Section:

(A) Generating electricity using renewable energy resources identified pursuant to item (4) of subsection (a) of this Section.

(B) Purchasing electricity generated using renewable energy resources identified pursuant to item (4) of subsection (a) of this Section through an energy contract.

(C) Purchasing renewable energy credits from renewable energy resources identified pursuant to item (4) of subsection (a) of this Section.

(D) Making an alternative compliance payment as described in subsection (d) of this Section.

(c) Use of renewable energy credits.

(1) Renewable energy credits that are not used by an alternative retail electric supplier to comply with a renewable portfolio standard in a compliance year may be banked and carried forward up to 2 12-month compliance periods after the compliance period in which the credit was generated for the purpose of complying with a renewable portfolio standard in those 2 subsequent compliance periods. For the 2009-2010 and 2010-2011 compliance periods, an alternative retail electric supplier may use renewable credits generated after December 31, 2008 and before June 1, 2009 to comply with this Section.

(2) An alternative retail electric supplier is responsible for demonstrating that a renewable energy credit used to comply with a renewable portfolio standard is derived from a renewable energy resource and that the alternative retail electric supplier has not used, traded, sold, or otherwise transferred the credit.

(3) The same renewable energy credit may be used by an alternative retail electric supplier to comply with a federal renewable portfolio standard and a renewable portfolio standard established under this Act. An alternative retail electric supplier that uses a renewable energy credit to comply with a renewable portfolio standard imposed by any other state may not use the same credit to comply with a renewable portfolio standard established under this Act.

(d) Alternative compliance payments.

(1) The Commission shall establish and post on its website, within 5 business days after entering an order approving a procurement plan pursuant to Section 1-75 of the Illinois Power Agency Act, maximum alternative compliance payment rates, expressed on a per kilowatt-hour basis, that will be applicable in the first compliance period following the plan approval. A separate maximum alternative compliance payment rate shall be established for the service territory of each electric utility that is subject to subsection (c) of Section 1-75 of the Illinois Power Agency Act. Each maximum alternative compliance payment rate shall be equal to the maximum allowable annual estimated average net increase due to the costs of the utility's purchase of renewable energy resources included in the amounts paid by eligible retail customers in connection with electric service, as described in item (2) of subsection (c) of Section 1-75 of the Illinois Power Agency Act for the compliance period, and as established in the approved procurement plan. Following each procurement event through which renewable energy resources are purchased for one or more of these utilities for the compliance period, the Commission shall establish and post on its website estimates of the alternative compliance payment rates, expressed on a per kilowatt-hour basis, that shall apply for that compliance period. Posting of the estimates shall occur no later than 10 business days following the procurement event, however, the Commission shall not be required to establish and post such estimates more often than once per calendar month. By July 1 of each year, the Commission shall establish and post on its website the actual alternative compliance payment rates for the preceding compliance year. For compliance years beginning prior to June 1, 2014, each alternative compliance payment rate shall be equal to the total amount of dollars that the utility contracted to spend on renewable resources, excepting the additional incremental cost attributable to solar resources, for the compliance period divided by the forecasted load of eligible retail customers, at the customers' meters, as previously established in the Commission-approved procurement plan for that compliance year. For compliance years commencing on or after June 1, 2014, each alternative compliance payment rate shall be equal to the total amount of dollars that the utility contracted to spend on all renewable resources for the compliance period divided by the forecasted load of retail customers for which the utility is procuring renewable energy resources in a given delivery year, at the customers' meters, as previously established in the Commission-approved procurement plan for that compliance year. The actual alternative compliance payment rates may not exceed the maximum alternative compliance payment rates established for the compliance period. For purposes of this subsection (d), the term "eligible retail customers" has the same meaning as found in Section 16-111.5 of this Act.

(2) In any given compliance year, an alternative retail electric supplier may elect to use alternative compliance payments to comply with all or a part of the applicable renewable portfolio standard. In the event that an alternative retail electric supplier elects to make alternative compliance payments to comply with all or a part of the applicable renewable portfolio standard, such payments shall be made by September 1, 2010 for the period of June 1, 2009 to May 1, 2010 and by September 1 of each year thereafter for the subsequent compliance period, in the manner and form as determined by the Commission. Any election by an alternative retail electric supplier to use alternative compliance payments is subject to review by the Commission under subsection (e) of this Section.

(3) An alternative retail electric supplier's alternative compliance payments shall be computed separately for each electric utility's service territory within which the alternative retail electric supplier provided retail service during the compliance period, provided that the electric utility was subject to subsection (c) of Section 1-75 of the Illinois Power Agency Act. For each service territory, the alternative retail electric supplier's alternative compliance payment shall be equal to (i) the actual alternative compliance payment rate established in item (1) of this subsection (d), multiplied by (ii) the actual amount of metered electricity delivered by the alternative retail electric supplier to retail customers for which the supplier has a compliance obligation within the service territory during the compliance period, multiplied by (iii) the result of one minus the ratios of the quantity of renewable energy resources used by the alternative retail electric supplier to comply with the requirements of this Section within the service territory to the product of the percentage of renewable energy resources required under item (3) or (3.5) of subsection (a) of this Section and the actual amount of metered electricity delivered by the alternative retail electrical supplier to retail customers for which the supplier has a compliance obligation within the service territory during the compliance period.

(4) Through May 31, 2017, all alternative compliance payments by alternative retail electric suppliers shall be deposited in the Illinois Power Agency Renewable Energy Resources Fund and used to purchase renewable energy credits, in accordance with Section 1-56 of the Illinois Power Agency Act. Beginning April 1, 2012 and by April 1 of each year thereafter, the Illinois Power Agency shall submit an annual report to the General Assembly, the Commission, and alternative retail electric suppliers that shall include, but not be limited to:

(A) the total amount of alternative compliance payments received in aggregate from alternative retail electric suppliers by planning year for all previous planning years in which the alternative compliance payment was in effect;

(B) the amount of those payments utilized to purchased renewable energy credits itemized by the date of each procurement in which the payments were utilized; and

(C) the unused and remaining balance in the Agency Renewable Energy Resources Fund attributable to those payments.

(4.5) Beginning with the delivery year commencing June 1, 2017, all alternative compliance payments by alternative retail electric suppliers shall be remitted to the applicable electric utility. To facilitate this remittance, each electric utility shall file a tariff with the Commission no later than 30 days following the effective date of this amendatory Act of the 99th General Assembly, which the Commission shall approve, after notice and hearing, no later than 45 days after its filing. The Illinois Power Agency shall use such payments to increase the amount of renewable energy resources otherwise to be procured under subsection (c) of Section 1-75 of the Illinois Power Agency Act.

(5) The Commission, in consultation with the Illinois Power Agency, shall establish a process or proceeding to consider the impact of a federal renewable portfolio standard, if enacted, on the operation of the alternative compliance mechanism, which shall include, but not be limited to, developing, to the extent permitted by the applicable federal statute, an appropriate methodology to apportion renewable energy credits retired as a result of alternative compliance payments made in accordance with this Section. The Commission shall commence any such process or proceeding within 35 days after enactment of a federal renewable portfolio standard.

(e) Each alternative retail electric supplier shall, by September 1, 2010 and by September 1 of each year thereafter, prepare and submit to the Commission a report, in a format to be specified by the Commission, that provides information certifying compliance by the alternative retail electric supplier with this Section, including copies of all PJM-GATS and M-RETS reports, and documentation relating to banking, retiring renewable energy credits, and any other information that the Commission determines necessary to ensure compliance with this Section.

An alternative retail electric supplier may file commercially or financially sensitive information or trade secrets with the Commission as provided under the rules of the Commission. To be filed confidentially, the information shall be accompanied by an affidavit that sets forth both the reasons for the confidentiality and a public synopsis of the information.

(f) The Commission may initiate a contested case to review allegations that the alternative retail electric supplier has violated this Section, including an order issued or rule promulgated under this Section. In any such proceeding, the alternative retail electric supplier shall have the burden of proof. If the Commission finds, after notice and hearing, that an alternative retail electric supplier has violated this Section, then the Commission shall issue an order requiring the alternative retail electric supplier to:

(1) immediately comply with this Section; and

(2) if the violation involves a failure to procure the requisite quantity of renewable energy resources or pay the applicable alternative compliance payment by the annual deadline, the Commission shall require the alternative retail electric supplier to double the applicable alternative compliance payment that would otherwise be required to bring the alternative retail electric supplier into compliance with this Section.

If an alternative retail electric supplier fails to comply with the renewable energy resource portfolio requirement in this Section more than once in a 5-year period, then the Commission shall revoke the alternative electric supplier's certificate of service authority. The Commission shall not accept an application for a certificate of service authority from an alternative retail electric supplier that has lost certification under this subsection (f), or any corporate affiliate thereof, for at least one year after the date of revocation.

(g) All of the provisions of this Section apply to electric utilities operating outside their service area except under item (2) of subsection (a) of this Section the quantity of renewable energy resources shall be measured as a percentage of the actual amount of electricity (megawatt-hours) supplied in the State outside of the utility's service territory during the 12-month period June 1 through May 31, commencing June 1, 2009, and the comparable 12-month period in each year thereafter except as provided in item (6) of subsection (a) of this Section.

If any such utility fails to procure the requisite quantity of renewable energy resources by the annual deadline, then the Commission shall require the utility to double the alternative compliance payment that would otherwise be required to bring the utility into compliance with this Section.

If any such utility fails to comply with the renewable energy resource portfolio requirement in this Section more than once in a 5-year period, then the Commission shall order the utility to cease all sales outside of the utility's service territory for a period of at least one year.

(h) The provisions of this Section and the provisions of subsection (d) of Section 16-115 of this Act relating to procurement of renewable energy resources shall not apply to an alternative retail electric supplier that operates a combined heat and power system in this State or that has a corporate affiliate that operates such a combined heat and power system in this State that supplies electricity primarily to or for the benefit of: (i) facilities owned by the supplier, its subsidiary, or other corporate affiliate; (ii) facilities electrically integrated with the electrical system of facilities owned by the supplier, its subsidiary, or other corporate affiliate; or (iii) facilities that are adjacent to the site on which the combined heat and power system is located.

(i) The obligations of alternative retail electric suppliers and electric utilities operating outside their service territories to procure renewable energy resources, make alternative compliance payments, and file annual reports, and the obligations of the Commission to determine and post alternative compliance payment rates, shall terminate after May 31, 2019, provided that alternative retail electric suppliers and electric utilities operating outside their service territories shall be obligated to make all alternative compliance payments that they were obligated to pay for periods through and including May 31, 2019, but were not paid as of that date. The Commission shall continue to enforce the payment of unpaid alternative compliance payments in accordance with subsections (f) and (g) of this Section. All alternative compliance payments made after May 31, 2016 shall be remitted to the applicable electric utility and used to purchase renewable energy credits, in accordance with Section 1-75 of the Illinois Power Agency Act.

This subsection (i) is intended to accommodate the transition to the procurement of renewable energy resources for all retail customers in the amounts specified under subsection (c) of Section 1-75 of the Illinois Power Agency Act and Section 16-111.5 of this Act, including but not limited to the transition to a single charge applicable to all retail customers to recover the costs of these resources. Each alternative retail electric supplier shall certify in its annual reports filed pursuant to subsection (e) of this Section after May 31, 2019, that its retail customers are not paying the costs of alternative compliance payments or renewable energy resources that the alternative retail electric supplier is not required to remit or purchase under this Section. The Commission shall have the authority to initiate an emergency rulemaking to adopt rules regarding such certification.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-115E)

Sec. 16-115E. Alternative retail electric supplier utility assistance recipient.

(a) Beginning January 1, 2020, an alternative retail electric supplier shall not knowingly submit an enrollment to change a customer's electric supplier if the electric utility's records indicate that the customer either received financial assistance in the previous 12 months from the Low Income Home Energy Assistance Program or, at the time of enrollment is participating in the Percentage of Income Payment Plan, unless (1) the customer's change in electric supplier is pursuant to a government aggregation program adopted in accordance with Section 1-92 of the Illinois Power Agency Act, or (2) the customer's change in electric supplier is pursuant to a Commission-approved savings guarantee plan as described in subsection (b).

(b) Beginning January 1, 2020, an alternative retail electric supplier may apply to the Commission to offer a savings guarantee plan to recipients of Low Income Home Energy Assistance Program funding or Percentage of Income Payment Plan funding. The Commission shall initiate a public, docketed proceeding to consider whether or not to approve an alternative retail electric supplier's application to offer a savings guarantee plan. At a minimum, the savings guarantee plan shall charge customers for electric supply at an amount that is less than the amount charged by the electric utility.

(c) An agreement entered into between an alternative retail electric supplier and a customer in violation of this Section is void and unenforceable. Before the electric utility executes a change in a customer's electric supplier, other than a change pursuant to a government aggregation program adopted in accordance with Section 1-92 of the Illinois Power Agency Act or a Commission-approved savings guarantee plan as described in subsection (b), the electric utility shall confirm at the time of the request whether its records indicate that the customer either has received financial assistance from the Low Income Home Energy Assistance Program in the previous 12 months or, at the time of enrollment, is participating in the Percentage of Income Payment Plan; and if so, shall reject such change request. Absent willful or wanton misconduct, no electric utility shall be held liable for any error in acting or failing to act pursuant to this Section.

(Source: P.A. 101-590, eff. 1-1-20.)

(220 ILCS 5/16-116)

Sec. 16-116. Commission oversight of electric utilities serving retail customers outside their service areas or providing competitive, non-tariffed services.

(a) An electric utility that has a tariff on file for delivery services may, without regard to any otherwise applicable tariffs on file, provide electric power and energy to one or more retail customers located outside its service area, but only to the extent (i) such retail customer (A) is eligible for delivery services under any delivery services tariff filed with the Commission by the electric utility in whose service area the retail customer is located and (B) has either elected to take such delivery services or has paid or contracted to pay the charges specified in Sections 16-108 and 16-114, or (ii) if such retail customer is served by a municipal system or electric cooperative, the customer is eligible for delivery services under the terms and conditions for such service established by the municipal system or electric cooperative serving that customer.

(b) An electric utility may offer any competitive service to any customer or group of customers without filing contracts with or seeking approval of the Commission, notwithstanding any rule or regulation that would require such approval. The Commission shall not increase or decrease the prices, and may not alter or add to the terms and conditions for the utility's competitive services, from those agreed to by the electric utility and the customer or customers. Non-tariffed, competitive services shall not be subject to the provisions of the Electric Supplier Act or to Articles V, VII, VIII or IX of the Act, except to the extent that any provisions of such Articles are made applicable to alternative retail electric suppliers pursuant to Sections 16-115 and 16-115A, but shall be subject to the provisions of subsections (b) through (g) of Section 16-115A, and Section 16-115B to the same extent such provisions are applicable to the services provided by alternative retail electric suppliers.

(c) Electric utilities serving retail customers outside their service areas shall be subject to the requirements of paragraph (5) of subsection (d) of Section 16-115 of the Public Utilities Act, except that the numerators referred to in that subsection (d) shall be the utility's retail market sales of electricity (expressed in kilowatthours sold) in the State outside of the utility's service territory in the prior month.

(Source: P.A. 95-1027, eff. 6-1-09.)

(220 ILCS 5/16-117)

Sec. 16-117. Commission consumer education program.

(a) The restructuring of the electricity industry will create a new electricity market with new marketers and sellers offering new goods and services, many of which the average consumer will not be able to readily evaluate. It is the intent of the General Assembly that (i) electricity consumers be provided with sufficient and reliable information so that they are able to compare and make informed selections of products and services provided in the electricity market; and (ii) mechanisms be provided to enable consumers to protect themselves from marketing practices that are unfair or abusive.

(b) The Commission shall maintain consumer education information to help residential and small commercial retail customers understand their service options in a competitive electric services market, and their rights and responsibilities.

(c) Not more than 90 days after the effective date of this amendatory Act of the 97th General Assembly, the Commission shall direct the Office of Retail Market Development to review the existing consumer education information for residential and small commercial customers and consider whether updates are necessary. The Office of Retail Market Development shall seek input from interested persons, including alternative retail electric suppliers, electric utilities, the Attorney General, and the Citizens Utility Board, to further its review of the consumer education materials and possible proposed changes. Within 4 months after the start of the review, the Office of Retail Market Development shall submit recommendations to the Commission for approval.

(d) (Blank).

(e) At a minimum, the consumer education information submitted to the Commission by the Office of Retail Market Development shall include concise explanations or descriptions of the following:

(1) the structure of the electric utility industry following this amendatory Act of 1997 and a glossary of basic terms;

(2) the choices available to consumers to take electric service from an alternative retail electric supplier or remain as a retail customer of an electric utility;

(3) a customer's rights, risks and responsibilities in receiving service from an alternative retail electric supplier or remaining as a retail customer of an electric utility;

(4) the legal obligations of alternative retail electric suppliers;

(5) those services that may be offered on a competitive basis in a deregulated electric services market, including services that could be packaged with the delivery of electric power and energy;

(6) services that an electric utility is required to provide pursuant to tariffed rates;

(7) the components of a bill that could be received by a customer taking delivery services;

(8) the complaint procedures set forth in Section 10-108 of this Act by which consumers may seek a redress of grievances against an electric utility or an alternative retail electric supplier and a list of phone numbers of the Commission, the Attorney General or other entities that can provide information and assistance to customers; and

(9) additional information available from the Commission upon request.

(f) Within 45 days following the submission required of the Office of Retail Market Development by subsection (c) of this Section, the Commission shall approve or disapprove the consumer education information.

(g) Once approved by the Commission, the consumer education information shall be provided as follows:

(1) If the electric utility bills residential or small commercial retail customers directly, then the bill shall include the Commission's electric education internet address in the space reserved for alternative retail electric supplier messages.

(2) Alternative retail electric suppliers shall provide the Commission's electric education internet address to all residential and small commercial retail customers.

(3) (Blank).

(4) The Commission shall make the following information available on its web site and printed information from the web site available to the public upon request and at no charge:

(A) all consumer education information developed by the Office of Retail Market Development and approved by the Commission;

(B) a list of all certified alternative retail electric suppliers serving residential and small commercial retail customers within the service territory of each electric utility;

(C) a list of alternative retail electric suppliers serving residential or small commercial retail customers which have been found in the last 3 years by the Commission pursuant to Section 10-108 to have failed to provide service in accordance with the terms of their contracts with such retail customers; and

(D) guidelines to assist customers in determining which energy supplier is most appropriate for each customer.

(h) The Commission may also adopt a uniform disclosure form which alternative retail electric suppliers would be required to complete enabling consumers to compare prices, terms and conditions offered by such suppliers.

(i) The Commission shall make available to the public staff with the ability and knowledge to respond to consumer inquiries.

(j) (Blank).

(k) (Blank).

(Source: P.A. 97-222, eff. 7-28-11.)

(220 ILCS 5/16-118)

Sec. 16-118. Services provided by electric utilities to alternative retail electric suppliers.

(a) It is in the best interest of Illinois energy consumers to promote fair and open competition in the provision of electric power and energy and to prevent anticompetitive practices in the provision of electric power and energy. Therefore, to the extent an electric utility provides electric power and energy or delivery services to alternative retail electric suppliers and such services are not subject to the jurisdiction of the Federal Energy Regulatory Commission, and are not competitive services, they shall be provided through tariffs that are filed with the Commission, pursuant to Article IX of this Act. Each electric utility shall permit alternative retail electric suppliers to interconnect facilities to those owned by the utility provided they meet established standards for such interconnection, and may provide standby or other services to alternative retail electric suppliers. The alternative retail electric supplier shall sign a contract setting forth the prices, terms and conditions for interconnection with the electric utility and the prices, terms and conditions for services provided by the electric utility to the alternative retail electric supplier in connection with the delivery by the electric utility of electric power and energy supplied by the alternative retail electric supplier.

(b) An electric utility shall file a tariff pursuant to Article IX of the Act that would allow alternative retail electric suppliers or electric utilities other than the electric utility in whose service area retail customers are located to issue single bills to the retail customers for both the services provided by such alternative retail electric supplier or other electric utility and the delivery services provided by the electric utility to such customers. The tariff filed pursuant to this subsection shall (i) require partial payments made by retail customers to be credited first to the electric utility's tariffed services, (ii) impose commercially reasonable terms with respect to credit and collection, including requests for deposits, (iii) retain the electric utility's right to disconnect the retail customers, if it does not receive payment for its tariffed services, in the same manner that it would be permitted to if it had billed for the services itself, and (iv) require the alternative retail electric supplier or other electric utility that elects the billing option provided by this tariff to include on each bill to retail customers an identification of the electric utility providing the delivery services and a listing of the charges applicable to such services. The tariff filed pursuant to this subsection may also include other just and reasonable terms and conditions. In addition, an electric utility, an alternative retail electric supplier or electric utility other than the electric utility in whose service area the customer is located, and a customer served by such alternative retail electric supplier or other electric utility, may enter into an agreement pursuant to which the alternative retail electric supplier or other electric utility pays the charges specified in Section 16-108, or other customer-related charges, including taxes and fees, in lieu of such charges being recovered by the electric utility directly from the customer.

(c) An electric utility with more than 100,000 customers shall file a tariff pursuant to Article IX of this Act that provides alternative retail electric suppliers, and electric utilities other than the electric utility in whose service area the retail customers are located, with the option to have the electric utility purchase their receivables for power and energy service provided to residential retail customers and non-residential retail customers with a non-coincident peak demand of less than 400 kilowatts. Receivables for power and energy service of alternative retail electric suppliers or electric utilities other than the electric utility in whose service area the retail customers are located shall be purchased by the electric utility at a just and reasonable discount rate to be reviewed and approved by the Commission after notice and hearing. The discount rate shall be based on the electric utility's historical bad debt and any reasonable start-up costs and administrative costs associated with the electric utility's purchase of receivables. The discounted rate for purchase of receivables shall be included in the tariff filed pursuant to this subsection (c). The discount rate filed pursuant to this subsection (c) shall be subject to periodic Commission review. The electric utility retains the right to impose the same terms on retail customers with respect to credit and collection, including requests for deposits, and retain the electric utility's right to disconnect the retail customers, if it does not receive payment for its tariffed services or purchased receivables, in the same manner that it would be permitted to if the retail customers purchased power and energy from the electric utility. The tariff filed pursuant to this subsection (c) shall permit the electric utility to recover from retail customers any uncollected receivables that may arise as a result of the purchase of receivables under this subsection (c), may also include other just and reasonable terms and conditions, and shall provide for the prudently incurred costs associated with the provision of this service pursuant to this subsection (c). Nothing in this subsection (c) permits the double recovery of bad debt expenses from customers.

(d) An electric utility with more than 100,000 customers shall file a tariff pursuant to Article IX of this Act that would provide alternative retail electric suppliers or electric utilities other than the electric utility in whose service area retail customers are located with the option to have the electric utility produce and provide single bills to the retail customers for both the electric power and energy service provided by the alternative retail electric supplier or other electric utility and the delivery services provided by the electric utility to the customers. The tariffs filed pursuant to this subsection shall require the electric utility to collect and remit customer payments for electric power and energy service provided by alternative retail electric suppliers or electric utilities other than the electric utility in whose service area retail customers are located. The tariff filed pursuant to this subsection shall require the electric utility to include on each bill to retail customers an identification of the alternative retail electric supplier or other electric utility that elects the billing option. The tariff filed pursuant to this subsection (d) may also include other just and reasonable terms and conditions and shall provide for the recovery of prudently incurred costs associated with the provision of service pursuant to this subsection (d). The costs associated with the provision of service pursuant to this Section shall be subject to periodic Commission review.

(e) An electric utility with more than 100,000 customers in this State shall file a tariff pursuant to Article IX of this Act that provides alternative retail electric suppliers, and electric utilities other than the electric utility in whose service area the retail customers are located, with the option to have the electric utility purchase 2 billing cycles worth of uncollectible receivables for power and energy service provided to residential retail customers and to non-residential retail customers with a non-coincident peak demand of less than 400 kilowatts upon returning that customer to that electric utility for delivery and energy service after that alternative retail electric supplier, or an electric utility other than the electric utility in whose service area the retail customer is located, has made reasonable collection efforts on that account. Uncollectible receivables for power and energy service of alternative retail electric suppliers, or electric utilities other than the electric utility in whose service area the retail customers are located, shall be purchased by the electric utility at a just and reasonable discount rate to be reviewed and approved by the Commission, after notice and hearing. The discount rate shall be based on the electric utility's historical bad debt for receivables that are outstanding for a similar length of time and any reasonable start-up costs and administrative costs associated with the electric utility's purchase of receivables. The discounted rate for purchase of uncollectible receivables shall be included in the tariff filed pursuant to this subsection (e). The electric utility retains the right to impose the same terms on these retail customers with respect to credit and collection, including requests for deposits, and retains the right to disconnect these retail customers, if it does not receive payment for its tariffed services or purchased receivables, in the same manner that it would be permitted to if the retail customers had purchased power and energy from the electric utility. The tariff filed pursuant to this subsection (e) shall permit the electric utility to recover from retail customers any uncollectable receivables that may arise as a result of the purchase of uncollectible receivables under this subsection (e), may also include other just and reasonable terms and conditions, and shall provide for the prudently incurred costs associated with the provision of this service pursuant to this subsection (e). Nothing in this subsection (e) permits the double recovery of utility bad debt expenses from customers. The electric utility may file a joint tariff for this subsection (e) and subsection (c) of this Section.

(f) Every alternative retail electric supplier or electric utility other than the electric utility in whose service area retail customers are located that issues single bills to the retail customers for the services provided by the alternative retail electric supplier or other electric utility to the customers shall include on the single bills issued to residential customers the current utility electric supply price to compare that would apply to the customer for the billing period if the customer obtained supply from the utility. The current utility electric supply price shall be the sum of the electric supply charge and the transmission services charge and shall disclose that the price does not include the monthly purchased electricity adjustment.

(g) Every electric utility that provides delivery and supply services shall include on each bill issued to residential customers who obtain supply from an alternative retail electric supplier the current utility electric supply price to compare that would apply to the customer for the billing period if the customer obtained supply from the utility. The current utility electric supply price to compare shall be the sum of the electric supply charge and the transmission services charge and shall disclose that the price does not include the monthly purchased electricity adjustment.

(Source: P.A. 101-590, eff. 1-1-20.)

(220 ILCS 5/16-119)

Sec. 16-119. Switching suppliers. An electric utility or an alternative retail electric supplier may establish a term of service, notice period for terminating service and provisions governing early termination through a tariff or contract. A customer may change its supplier subject to tariff or contract terms and conditions. Any notice provisions; or provision for a fee, charge or penalty with early termination of a contract; shall be conspicuously disclosed in any tariff or contract. Any tariff filed or contract renewed or entered into on and after the effective date of this amendatory Act of the 99th General Assembly that contains an early termination clause shall disclose the amount of the early termination fee or penalty, provided that any early termination fee or penalty shall not exceed $50 total for residential customers and $150 for small commercial retail customers as defined in Section 16-102 of this Act, regardless of whether or not the tariff or contract is a multiyear tariff or contract. Beginning January 1, 2020, residential and small commercial retail customers shall have a right to terminate their contracts with alternative retail electric suppliers at any time without any termination fees or penalties. A customer shall remain responsible for any unpaid charges owed to an electric utility or alternative retail electric supplier at the time it switches to another provider.

The caps on early termination fees and penalties under this Section shall apply only to early termination fees and penalties for early termination of electric service. The caps shall not apply to charges or fees for devices, equipment, or other services provided by the utility or alternative retail electric supplier.

(Source: P.A. 101-590, eff. 1-1-20.)

(220 ILCS 5/16-119A)

Sec. 16-119A. Functional separation.

(a) Within 90 days after the effective date of this amendatory Act of 1997, the Commission shall open a rulemaking proceeding to establish standards of conduct for every electric utility described in subsection (b). To create efficient competition between suppliers of generating services and sellers of such services at retail and wholesale, the rules shall allow all customers of a public utility that distributes electric power and energy to purchase electric power and energy from the supplier of their choice in accordance with the provisions of Section 16-104. In addition, the rules shall address relations between providers of any 2 services described in subsection (b) to prevent undue discrimination and promote efficient competition. Provided, however, that a proposed rule shall not be published prior to May 15, 1999.

(b) The Commission shall also have the authority to investigate the need for, and adopt rules requiring, functional separation between the generation services and the delivery services of those electric utilities whose principal service area is in Illinois as necessary to meet the objective of creating efficient competition between suppliers of generating services and sellers of such services at retail and wholesale. After January 1, 2003, the Commission shall also have the authority to investigate the need for, and adopt rules requiring, functional separation between an electric utility's competitive and non-competitive services.

(b-5) If there is a change in ownership of a majority of the voting capital stock of an electric utility or the ownership or control of any entity that owns or controls a majority of the voting capital stock of an electric utility, the electric utility shall have the right to file with the Commission a new plan. The newly filed plan shall supersede any plan previously approved by the Commission pursuant to this Section for that electric utility, subject to Commission approval. This subsection only applies to the extent that the Commission rules for the functional separation of delivery services and generation services provide an electric utility with the ability to select from 2 or more options to comply with this Section. The electric utility may file its revised plan with the Commission up to one calendar year after the conclusion of the sale, purchase, or any other transfer of ownership described in this subsection. In all other respects, an electric utility must comply with the Commission rules in effect under this Section. The Commission may promulgate rules to implement this subsection. This subsection shall have no legal effect after January 1, 2005.

(c) In establishing or considering the need for rules under subsections (a) and (b), the Commission shall take into account the effects on the cost and reliability of service and the obligation of the utility to provide bundled service under this Act. The Commission shall adopt rules that are a cost effective means to ensure compliance with this Section.

(d) Nothing in this Section shall be construed as imposing any requirements or obligations that are in conflict with federal law.

(e) Notwithstanding anything to the contrary, an electric utility may market and promote the services, rates and programs authorized by Sections 16-107, and 16-108.6 of this Act.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-120)

Sec. 16-120. Development of competitive market; Commission study and reports; investigation.

(a) On or before December 31, 1999 and once every 3 years thereafter, the Commission shall monitor and analyze patterns of entry and exit, applications for entry and exit, and any barriers to entry or participation that may exist, for services provided under this Article; shall analyze any impediments to the establishment of a fully competitive energy and power market in Illinois; and shall include its findings together with appropriate recommendations for legislative action in a report to the General Assembly.

(b) Beginning in 2001, and ending in 2006, the Commission shall prepare an annual report regarding the development of electricity markets in Illinois which shall be filed by April 1 of each year with the Joint Committee on Legislative Support Services of the General Assembly and the Governor and which shall be publicly available. Such report shall include, at a minimum, the following information:

(1) the aggregate annual peak demand of retail customers in the State of Illinois in the preceding calendar year;

(2) the total annual kilowatt-hours delivered and sold to retail customers in the State of Illinois by each electric utility within its own service territory, each electric utility outside its service territory, and alternative retail electric suppliers in the preceding calendar year;

(3) the percentage of the total kilowatt-hours delivered and sold to retail customers in the State of Illinois in the preceding calendar year by each electric utility within its service territory, each electric utility outside its service territory, and each alternative retail electric supplier; and

(4) any other information the Commission considers significant in assessing the development of Illinois electricity markets, which may include, to the extent available, information similar to that described in items 1, 2 and 3 with respect to cogeneration, self-generation and other sources of electric power and energy provided to customers that do not take delivery services or bundled electric utility services.

The Commission may also include such other information as it deems to be necessary or beneficial in describing or explaining the results of its Report. The Report required by this Section shall be adopted by a vote of the full Commission prior to filing. Proprietary or confidential information shall not be disclosed publicly. Nothing contained in this Section shall prohibit the Commission from taking actions that would otherwise be allowed under this Act.

(c) The Commission shall prepare a report on the value of municipal aggregation of electricity customers. The report shall be filed with the General Assembly and the Governor no later than January 15, 2003 and shall be publicly available. The report shall, at a minimum, include:

(1) a description and analysis of actual and potential forms of aggregation of electricity customers in Illinois and in the other states, including aggregation through municipal, affinity, and other organizations and through aggregation of consumer purchases of electricity from renewable energy sources;

(2) estimates of the potential benefits of municipal aggregation to Illinois electricity customers in at least 5 specific municipal examples comparing their costs under bundled rates and unbundled rates, including real-time prices;

(3) a description of the barriers to municipal and other forms of aggregation in Illinois, including legal, economic, informational, and other barriers; and

(4) options for legislative action to foster municipal and other forms of aggregation of electricity customers.

In preparing the report, the Commission shall consult with persons involved in aggregation or the study of aggregation of electricity customers in Illinois, including municipalities, utilities, aggregators, and non-profit organizations. The provisions of Section 16-122 notwithstanding, the Commission may request and utilities shall provide such aggregated load data as may be necessary to perform the analyses required by this subsection; provided, however, proprietary or confidential information shall not be disclosed publicly.

(Source: P.A. 92-585, eff. 6-26-02.)

(220 ILCS 5/16-121)

Sec. 16-121. Non-discrimination; adoption of rules and regulations. The Commission shall adopt rules and regulations no later than 180 days after the effective date of this amendatory Act of 1997 governing the relationship between the electric utility and its affiliates, and ensuring nondiscrimination in services provided to the utility's affiliate and any alternative retail electric supplier, including without limitation, cost allocation, cross-subsidization and information sharing.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-122)

Sec. 16-122. Customer information.

(a) Upon the request of a retail customer, or a person who presents verifiable authorization and is acting as the customer's agent, and payment of a reasonable fee, electric utilities shall provide to the customer or its authorized agent the customer's billing and usage data.

(b) Upon request from any alternative retail electric supplier and payment of a reasonable fee, an electric utility serving retail customers in its service area shall make available generic information concerning the usage, load shape curve or other general characteristics of customers by rate classification. Provided however, no customer specific billing, usage or load shape data shall be provided under this subsection unless authorization to provide such information is provided by the customer pursuant to subsection (a) of this Section.

Notwithstanding the requirements of this Section, if an alternative retail electric supplier warrants to an electric utility serving more than 500,000 retail customers that the alternative retail electric supplier's customer has provided consent as described in subsection (d-5) of Section 2EE of the Consumer Fraud and Deceptive Business Practices Act, then until either the customer contacts the alternative retail electric supplier to opt out or the customer is no longer served by the alternative retail electric supplier:

(1) An electric utility serving more than 500,000 retail customers shall electronically transmit interval meter usage data at the end of each monthly billing period for each residential retail customer for which the alternative retail electric supplier is providing electric power and energy supply service, for which the alternative retail electric supplier has requested such information, and for which the electric utility meters the residential customer using automated metering infrastructure equipment. Such data transmission shall occur no later than one business day after the electric utility serving more than 500,000 retail customers validates the interval meter usage data with the monthly billing period for such residential retail customer through an electronic data interchange or secure interface for which the alternative retail electric supplier has requested such information and upon payment of a reasonable and amortized fee to recover the utility's prudently and reasonably incurred costs, approved by the Commission after notice and hearing, to provide this service. The interval meter usage data shall be provided at a minimum on an hourly basis or on a 30-minute basis. In addition, not later than the following day, the electric utility shall provide unverified interval data through an electronic data interchange or secure interface for which the alternative retail electric supplier has requested such information and upon payment of a reasonable and amortized fee to recover the utility's prudently and reasonably incurred costs, approved by the Commission after notice and hearing, to provide this service. The unverified interval meter usage data shall be provided at a minimum on an hourly basis or on a 30-minute basis. The same processes shall apply for nonresidential retail customers.

(2) An electric utility serving more than 500,000 retail customers shall submit tariffs to the Commission for approval within 120 days of the effective date of this amendatory Act of the 103rd General Assembly to meet the minimum requirements of paragraph (1) and provide such services no later than June 1, 2025. The Commission shall issue an order approving, or approving with modification to ensure compliance with this Section, the tariff no later than 240 days after such filing of the tariffs filed as described in this Section.

(3) Nothing in this amendatory Act of the 103rd General Assembly prohibits such utility proposing new tariffs as described in Article IX to the extent such tariffs are consistent with the requirements of this amendatory Act of the 103rd General Assembly. Nothing in this amendatory Act of the 103rd General Assembly shall require such electric utility to alter its tariffs or practices to the extent that they: (i) provide interval data with shorter intervals; (ii) provide interval data more frequently than monthly; or (iii) provide other enhancements beyond the minimum standards required by paragraph (1).

(4) An alternative retail electric supplier shall use such interval meter usage data exclusively for the development, marketing, and provision of current and future products and services to enable such customers to more easily and effectively manage their energy consumption, including, but not limited to, time-of-use pricing, demand response, energy efficiency or management, beneficial electrification, on-site or community generation, or any other electricity-related products or services or customer billing or as otherwise authorized by the Commission.

(5) An alternative retail electric supplier shall not sell interval data obtained under this Section. An alternative retail electric supplier shall not provide, share, or otherwise disclose a consumer's interval meter data obtained under this Section, except an alternative retail electric supplier may license or disclose a customer's interval meter data obtained under this Section if the following conditions are met: (i) the license or disclosure is made to an alternative retail electric supplier's affiliate or a third party with which the alternative retail electric supplier has a contract; (ii) the disclosure of a customer's interval meter data is made only to perform the following functions on behalf of the alternative retail electric supplier: billing and invoicing, administration of the product or service provided to the customer, or pricing products and services for the customer; and (iii) the alternative retail electric supplier maintains responsibility for ensuring that its affiliates and contracted third parties purge such data upon termination of their contract, ownership, affiliation, or license or other agreement, or to the extent that the customer interval data is no longer necessary for the affiliate or contracted third party to perform the function for which the customer interval data was provided. An alternative retail electric supplier may not provide a customer's interval meter data obtained under this Section to a sales agent, broker, or consultant for the purpose of marketing to that specific customer. An alternative retail electric supplier shall be strictly liable under the Consumer Fraud and Deceptive Business Practices Act, this Act, and any other applicable law for any improper or unauthorized disclosure of customer interval data by it or any entity to which it discloses such customer interval data, regardless of whether such data was disclosed under the terms of this Section.

(6) Nothing in this Section prohibits an electric utility serving more than 500,000 retail customers from providing interval metering data to an alternative retail electric supplier as otherwise authorized by law or order of the Commission.

(7) The Commission shall set such fee, after notice and hearing pursuant to paragraph (1) and cost recovery to provide data or services, including any and all data or services provided or proposed under paragraphs (1) through (3) or otherwise authorized by this amendatory Act of the 103rd General Assembly, which shall be designed to obtain cost recovery solely from alternative retail electric suppliers. The fee shall be paid by all alternative retail electric suppliers that are authorized to provide service to residential customers in the electric utility's service territory on a periodic basis as set forth in the tariff. The Commission shall not establish a fee that is so high as to deter competition or competitive supply offerings in the State, or deny a utility a reasonable opportunity to recover its cost of providing public utility service pursuant to this Act. The Commission may at any time review the reasonableness of the fee established pursuant to this Section upon its own motion or petition of an interested party.

(c) Upon request from a unit of local government and payment of a reasonable fee, an electric utility shall make available information concerning the usage, load shape curves, and other characteristics of customers by customer classification and location within the boundaries of the unit of local government, however, no customer specific billing, usage, or load shape data shall be provided under this subsection unless authorization to provide that information is provided by the customer. This subsection (c) does not prohibit an electric utility from providing a unit of local government or its designated auditor the materials delineated in Section 8-11-2.5 of the Illinois Municipal Code for the purposes of an audit under that Section.

(d) All such customer information shall be made available in a timely fashion in an electronic format, if available.

(Source: P.A. 102-1144, eff. 3-17-23; 103-237, eff. 6-30-23.)

(220 ILCS 5/16-123)

Sec. 16-123. Establishment of customer information centers for electric utilities and alternative retail electric suppliers.

(a) All electric utilities and alternative retail electric suppliers shall be required to maintain a customer call center where customers can reach a representative and receive current information. Customers shall periodically be notified on how to reach the call center. The Commission shall have the authority to establish reporting requirements for such centers.

(b) Notwithstanding anything to the contrary, an electric utility may:

(1) disclose the current utility electric supply price to a retail customer who takes electric power and energy supply service from an alternative retail electric supplier;

(2) disclose the supply price the customer is paying as reflected on the customer's bill, if known;

(3) furnish to a retail customer a list of frequently asked questions to be used by the retail customer in evaluating electric power and energy supply rate offers by alternative retail electric suppliers; this list may include, but is not limited to, the following:

(A) length of the contract;

(B) the price per kilowatt hour, and whether the contract price is fixed or variable, and if variable, the circumstances under which the price may change;

(C) whether penalties or early termination fees apply if the customer terminates the contract before the expiration of its term; and

(D) whether the customer may be subject to any other adjustments, penalties, surcharges, or costs beyond the electric power and energy supply rate; and

(4) provide to a retail customer education information published by the Office of Retail Market Development and the Office of the Attorney General regarding the selection and evaluation of electric power and energy supply rate offers by alternative retail electric suppliers.

(Source: P.A. 101-590, eff. 1-1-20.)

(220 ILCS 5/16-124)

Sec. 16-124. Metering for residential and small commercial retail customers. An electric utility shall not require a residential or small commercial retail customer to take additional metering or metering capability as a condition of taking delivery services unless the Commission finds, after notice and hearing, that additional metering or metering capability is required to meet reliability requirements. Alternative retail electric suppliers serving such customers may provide such additional metering or metering capability at their own expense or take such additional metering or metering capability from the utility as a tariffed service. Any additional metering requirements shall be imposed in a nondiscriminatory manner. Nothing in this subsection shall be construed to prevent the normal maintenance, replacement or upgrade of meters as required to comply with Commission rules.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-125)

Sec. 16-125. Transmission and distribution reliability requirements.

(a) To assure the reliable delivery of electricity to all customers in this State and the effective implementation of the provisions of this Article, the Commission shall, within 180 days of the effective date of this Article, adopt rules and regulations for assessing and assuring the reliability of the transmission and distribution systems and facilities that are under the Commission's jurisdiction.

(b) These rules and regulations shall require each electric utility or alternative retail electric supplier owning, controlling, or operating transmission and distribution facilities and equipment subject to the Commission's jurisdiction, referred to in this Section as "jurisdictional entities", to adopt and implement procedures for restoring transmission and distribution services to customers after transmission or distribution outages on a nondiscriminatory basis without regard to whether a customer has chosen the electric utility, an affiliate of the electric utility, or another entity as its provider of electric power and energy. These rules and regulations shall also, at a minimum, specifically require each jurisdictional entity to submit annually to the Commission.

(1) the number and duration of planned and unplanned outages during the prior year and their impacts on customers;

(2) outages that were controllable and outages that were exacerbated in scope or duration by the condition of facilities, equipment or premises or by the actions or inactions of operating personnel or agents;

(3) customer service interruptions that were due solely to the actions or inactions of an alternative retail electric supplier or a public utility in supplying power or energy;

(4) a detailed report of the age, current condition, reliability and performance of the jurisdictional entity's existing transmission and distribution facilities, which shall include, without limitation, the following data:

(i) a summary of the jurisdictional entity's outages and voltage variances reportable under the Commission's rules;

(ii) the jurisdictional entity's expenditures for transmission construction and maintenance, the ratio of those expenditures to the jurisdictional entity's transmission investment, and the average remaining depreciation lives of the entity's transmission facilities, expressed as a percentage of total depreciation lives;

(iii) the jurisdictional entity's expenditures for distribution construction and maintenance, the ratio of those expenditures to the jurisdictional entity's distribution investment, and the average remaining depreciation lives of the entity's distribution facilities, expressed as a percentage of total depreciation lives;

(iv) a customer satisfaction survey covering, among other areas identified in Commission rules, reliability, customer service, and understandability of the jurisdictional entity's services and prices; and

(v) the corresponding information, in the same format, for the previous 3 years, if available;

(5) a plan for future investment and reliability improvements for the jurisdictional entity's transmission and distribution facilities that will ensure continued reliable delivery of energy to customers and provide the delivery reliability needed for fair and open competition; and

(6) a report of the jurisdictional entity's implementation of its plan filed pursuant to subparagraph (5) for the previous reporting period.

(c) The Commission rules shall set forth the criteria that will be used to assess each jurisdictional entity's annual report and evaluate its reliability performance. Such criteria must take into account, at a minimum: the items required to be reported in subsection (b); the relevant characteristics of the area served; the age and condition of the system's equipment and facilities; good engineering practices; the costs of potential actions; and the benefits of avoiding the risks of service disruption.

(d) At least every 3 years, beginning in the year the Commission issues the rules required by subsection (a) or the following year if the rules are issued after June 1, the Commission shall assess the annual report of each jurisdictional entity and evaluate its reliability performance. The Commission's evaluation shall include specific identification of, and recommendations concerning, any potential reliability problems that it has identified as a result of its evaluation.

(e) In the event that more than either (i) 30,000 (or some other number, but only as provided by statute) of the total customers or (ii) 0.8% (or some other percentage, but only as provided by statute) of the total customers, whichever is less, of an electric utility are subjected to a continuous power interruption of 4 hours or more that results in the transmission of power at less than 50% of the standard voltage, or that results in the total loss of power transmission, the utility shall be responsible for compensating customers affected by that interruption for 4 hours or more for all actual damages, which shall not include consequential damages, suffered as a result of the power interruption. The utility shall also reimburse the affected municipality, county, or other unit of local government in which the power interruption has taken place for all emergency and contingency expenses incurred by the unit of local government as a result of the interruption. A waiver of the requirements of this subsection may be granted by the Commission in instances in which the utility can show that the power interruption was a result of any one or more of the following causes:

(1) Unpreventable damage due to weather events or conditions.

(2) Customer tampering.

(3) Unpreventable damage due to civil or international unrest or animals.

(4) Damage to utility equipment or other actions by a party other than the utility, its employees, agents, or contractors.

Loss of revenue and expenses incurred in complying with this subsection may not be recovered from ratepayers.

(f) In the event of a power surge or other fluctuation that causes damage and affects more than either (i) 30,000 (or some other number, but only as provided by statute) of the total customers or (ii) 0.8% (or some other percentage, but only as provided by statute) of the total customers, whichever is less, the electric utility shall pay to affected customers the replacement value of all goods damaged as a result of the power surge or other fluctuation unless the utility can show that the power surge or other fluctuation was due to one or more of the following causes:

(1) Unpreventable damage due to weather events or conditions.

(2) Customer tampering.

(3) Unpreventable damage due to civil or international unrest or animals.

(4) Damage to utility equipment or other actions by a party other than the utility, its employees, agents, or contractors.

Loss of revenue and expenses incurred in complying with this subsection may not be recovered from ratepayers. Customers with respect to whom a waiver has been granted by the Commission pursuant to subparagraphs (1)-(4) of subsections (e) and (f) shall not count toward the either (i) 30,000 (or some other number, but only as provided by statute) of the total customers or (ii) 0.8% (or some other percentage, but only as provided by statute) of the total customers required therein.

(g) Whenever an electric utility must perform planned or routine maintenance or repairs on its equipment that will result in transmission of power at less than 50% of the standard voltage, loss of power, or power fluctuation (as defined in subsection (f)), the utility shall make reasonable efforts to notify potentially affected customers no less than 24 hours in advance of performance of the repairs or maintenance.

(h) Remedies provided for under this Section may be sought exclusively through the Illinois Commerce Commission as provided under Section 10-109 of this Act. Damages awarded under this Section for a power interruption shall be limited to actual damages, which shall not include consequential damages, and litigation costs. A utility's request for a waiver of this Section shall be timely if filed no later than 30 days after the date on which a claim is filed with the Commission seeking damages or expense reimbursement under this Section. No utility shall be liable under this Section while a request for waiver is pending. Damage awards may not be paid out of utility rate funds.

(i) The provisions of this Section shall not in any way diminish or replace other civil or administrative remedies available to a customer or a class of customers.

(j) The Commission shall by rule require an electric utility to maintain service records detailing information on each instance of transmission of power at less than 50% of the standard voltage, loss of power, or power fluctuation (as defined in subsection (f)), that affects 10 or more customers. Occurrences that are momentary shall not be required to be recorded or reported. The service record shall include, for each occurrence, the following information:

(1) The date.

(2) The time of occurrence.

(3) The duration of the incident.

(4) The number of customers affected.

(5) A description of the cause.

(6) The geographic area affected.

(7) The specific equipment involved in the fluctuation or interruption.

(8) A description of measures taken to restore service.

(9) A description of measures taken to remedy the cause of the power interruption or fluctuation.

(10) A description of measures taken to prevent future occurrence.

(11) The amount of remuneration, if any, paid to affected customers.

(12) A statement of whether the fixed charge was waived for affected customers.

Copies of the records containing this information shall be available for public inspection at the utility's offices, and copies thereof may be obtained upon payment of a fee not exceeding the reasonable cost of reproduction. A copy of each record shall be filed with the Commission and shall be available for public inspection. Copies of the records may be obtained upon payment of a fee not exceeding the reasonable cost of reproduction.

(k) The requirements of subsections (e) through (j) of this Section shall apply only to an electric public utility having 100,000 or more customers.

(Source: P.A. 95-1027, eff. 6-1-09.)

(220 ILCS 5/16-125A)

Sec. 16-125A. Consolidated billing provision for established intergovernmental agreement participants.

(a) The tariffs of each electric utility serving at least 1,000,000 customers shall permit governmental customers acting through an intergovernmental agreement that was in effect 30 days prior to the date specified in subsection (b) and which provides for these governmental customers to work cooperatively in the purchase of electric energy to aggregate their monthly kilowatt-hour energy usage and monthly kilowatt billing demand.

(b) In implementing the provisions of this Section, the rates and charges applicable under the combined billing tariff of the serving utility in effect on May 1, 1997 shall apply to all load of eligible government customers selected by the governmental customers including, but not limited to, load served under contract.

(c) For purposes of this Section, "governmental customers" shall mean any customer that is a municipality, municipal corporation, unit of local government, park district, school district, community college district, forest preserve district, special district, public corporation, body politic and corporate, sanitary or water reclamation district, or other local government agencies, including any entity created by intergovernmental agreement among any of the foregoing entities to implement the arrangements permitted by subsections (a) and (b) of this Section.

(d) Electric utilities shall file tariffs that comply with the requirements of this Section within 60 days after the effective date of this amendatory Act of 1997.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-126)

Sec. 16-126. Membership in an independent system operator.

(a) The General Assembly finds that the establishment of one or more independent system operators or their functional equivalents is required to facilitate the development of an open and efficient marketplace for electric power and energy to the benefit of Illinois consumers. Therefore, each Illinois electric utility owning or controlling transmission facilities or providing transmission services in Illinois and that is a member of the Mid-American Interconnected Network as of the effective date of this amendatory Act of 1997 shall submit for approval to the Federal Energy Regulatory Commission an application for establishing or joining an independent system operator that shall:

(1) independently manage and control transmission facilities of any electric utility;

(2) provide for nondiscriminatory access to and use of the transmission system for buyers and sellers of electricity;

(3) direct the transmission activities of the control area operators;

(4) coordinate, plan, and order the installation of new transmission facilities;

(5) adopt inspection, maintenance, repair, and replacement standards for the transmission facilities under its control and direct maintenance, repair, and replacement of all facilities under its control; and

(6) implement procedures and act to assure the provision of adequate and reliable service.

These standards shall be consistent with reliability criteria no less stringent than those established by the Mid-American Interconnected Network and the North American Electric Reliability Council or their successors.

(b) The requirements of this Section may be met by joining or establishing a regional independent system operator that meets the criteria enumerated in subsections (a), (c), and (d) of this Section, as determined by the Commission. To achieve the objectives set forth in subsection (a), the State of Illinois, through the appropriate officers, departments, and agencies, shall work cooperatively with the appropriate officials and agencies of those States contiguous to this State and the Federal Energy Regulatory Commission towards the formation of one or more regional independent system operators.

(c) The independent system operator's governance structure must be fair and nondiscriminatory, and the independent system operator must be independent of any one market participant or class of participants. The independent system operator's rules of governance must prevent control, or the appearance of control, of decision-making by any class of participants.

(d) Participants in the independent system operator shall make available to the independent system operator all information required by the independent system operator in performance of its functions described herein. The independent system operator and the electric utilities participating in the independent system operator shall make all filings required by the Federal Energy Regulatory Commission. The independent system operator shall ensure that additional filings at the Federal Energy Regulatory Commission request confirmation of the relevant provisions of this amendatory Act of 1997.

(e) If a spot market, exchange market, or other market-based mechanism providing transparent real-time market prices for electric power has not been developed, the independent system operator or a closely cooperating agent of the independent system operator may provide an efficient competitive power exchange auction for electric power and energy, open on a nondiscriminatory basis to all suppliers, which meets the loads of all auction customers at efficient prices.

(f) For those electric utilities referred to in subsection (a) which have not filed with the Federal Energy Regulatory Commission by June 30, 1998 an application for establishment or participation in an independent system operator or if such application has not been approved by the Federal Energy Regulatory Commission by March 31, 1999, a 5 member Oversight Board shall be formed. The Oversight Board shall (1) oversee the creation of an Illinois independent system operator and (2) determine the composition and initial terms of service of, and appoint the initial members of, the Illinois independent system operator board of directors. The Oversight Board shall consist of the following: (1) 3 persons appointed by the Governor; (2) one person appointed by the Speaker of the House of Representatives; and (3) one person appointed by the President of the Senate. The Oversight Board shall take the steps that are necessary to ensure the earliest possible incorporation of an Illinois independent system operator under the Business Corporation Act of 1983, and shall serve until the Illinois independent system operator is incorporated.

(g) After notice and hearing, the Commission shall require each electric utility referred to in subsection (a), that is not participating in an independent system operator meeting the requirements of subsections (a) and (c), to seek authority from the Federal Energy Regulatory Commission to transfer functional control of transmission facilities to the Illinois independent system operator for control by the Illinois independent system operator consistent with the requirements of subsection (a). Upon approval by the Federal Energy Regulatory Commission, electric utilities may also elect to transfer ownership of transmission facilities to the Illinois independent system operator. Nothing in this Act shall be deemed to preclude the Illinois independent system operator from (1) seeking authority, as necessary, to merge with or otherwise combine its operations with those of one or more other entities authorized to provide transmission services, (2) purchasing or leasing transmission assets from transmission-owning entities not required by this Section to lease transmission facilities to the Illinois independent system operator, or (3) operating as a transmission public utility under the Federal Power Act.

(h) Any other owner of transmission facilities in Illinois not required by this Section to participate in an independent system operator shall be permitted, but not required, to become a member of the Illinois independent system operator.

(i) The Illinois independent system operator created under this Section, and any other independent system operator authorized by the Federal Energy Regulatory Commission to provide transmission services as a public utility under the Federal Power Act within the State of Illinois, shall be deemed to be a public utility for purposes of Section 8-503 and 8-509 of this Act. An independent system operator or regional transmission organization that is the subject of an order entered by the Commission under Section 8-503 need not possess a certificate of service authority under Section 8-406 in order to be authorized to take the actions set forth in Section 8-509.

(j) Electric utilities referred to in subsection (a) may withdraw from the Illinois independent system operator upon becoming a member of an independent system operator or operators conforming with the criteria in subsections (a) and (c) and whose formation and operation has been approved by the Federal Energy Regulatory Commission. This subsection does not relieve any electric utility of any obligations under Federal law.

(k) Nothing in this Section shall be construed as imposing any requirements or obligations that are in conflict with federal law.

(l) A regional transmission organization created under the rules of the Federal Energy Regulatory Commission shall be considered to be the functional equivalent of an independent system operator for purposes of this Section, and an electric utility shall be deemed to meet its obligations under this Section through membership in a regional transmission organization that fulfills the requirements of an independent system operator under this Section.

(Source: P.A. 92-12, eff. 7-1-01.)

(220 ILCS 5/16-126.1)

Sec. 16-126.1. Regional transmission organization memberships. The State shall not directly or indirectly prohibit an electric utility that on December 31, 2005 provided electric service to at least 100,000 customers in Illinois from membership in a Federal Energy Regulatory Commission approved regional transmission organization of its choosing. Nothing in this Section limits any authority the Commission otherwise has to regulate that electric utility. This Section ceases to be effective on July 1, 2022 unless extended by the General Assembly by law.

(Source: P.A. 95-481, eff. 8-28-07.)

(220 ILCS 5/16-127)

Sec. 16-127. Environmental disclosure.

(a) Every electric utility and alternative retail electric supplier shall provide the following information, to the maximum extent practicable, to its customers on a quarterly basis:

(i) the known sources of electricity supplied, broken-out by percentages, of biomass power, coal-fired power, hydro power, natural gas-fired power, nuclear power, oil-fired power, solar power, wind power and other resources, respectively;

(ii) a pie chart that graphically depicts the percentages of the sources of the electricity supplied as set forth in subparagraph (i) of this subsection;

(iii) a pie chart that graphically depicts the quantity of renewable energy resources procured pursuant to Section 1-75 of the Illinois Power Agency Act as a percentage of electricity supplied to serve eligible retail customers as defined in Section 16-111.5(a) of this Act; and

(iv) a pie chart that graphically depicts the quantity of zero emission credits from zero emission facilities procured under Section 1-75 of the Illinois Power Agency Act as a percentage of the actual load of retail customers within its service area and, for an electric utility serving over 3,000,000 customers, the quantity of carbon mitigation credits from carbon-free energy resources procured under Section 1-75 of the Illinois Power Agency Act, which may be depicted in combination with the zero emission credits procured.

(b) In addition, every electric utility and alternative retail electric supplier shall provide, to the maximum extent practicable, to its customers on a quarterly basis, a standardized chart in a format to be determined by the Commission in a rule following notice and hearings which provides the amounts of carbon dioxide, nitrogen oxides and sulfur dioxide emissions and nuclear waste attributable to the known sources of electricity supplied as set forth in subparagraph (i) of subsection (a) of this Section.

(c) The electric utilities and alternative retail electric suppliers may provide their customers with such other information as they believe relevant to the information required in subsections (a) and (b) of this Section. All of the information required in subsections (a) and (b) of this Section shall be made available by the electric utilities or alternative retail electric suppliers either in an electronic medium, such as on a website or by electronic mail, or through the U.S. Postal Service.

(d) For the purposes of subsection (a) of this Section, "biomass" means dedicated crops grown for energy production and organic wastes.

(e) All of the information provided in subsections (a) and (b) of this Section shall be presented to the Commission for inclusion in its World Wide Web Site.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/16-128)

Sec. 16-128. Provisions related to utility employees.

(a) The General Assembly finds:

(1) The reliability and safety of the electric system has depended and depends on a workforce of skilled and dedicated employees, equipped with technical training and experience.

(2) The integrity and reliability of the system also requires the industry's commitment to invest in regular inspection and maintenance, to assure that it can withstand the demands of heavy service requirements and emergency situations.

(3) It is in the State's interest to protect the interests of utility employees who have and continue to dedicate themselves to assuring reliable service to the citizens of this State, and who might otherwise be economically displaced in a restructured industry.

The General Assembly further finds that it is necessary to assure that employees of electric utilities and employees of contractors or subcontractors performing work on behalf of an electric utility operating in the deregulated industry have the requisite skills, knowledge, training, experience, and competence to provide reliable and safe electrical service under this Act.

The General Assembly also finds that it is necessary to assure that employees of alternative retail electric suppliers and employees of contractors or subcontractors performing work on behalf of an alternative retail electric supplier operating in the deregulated industry have the requisite skills, knowledge, training, experience, and competence to provide reliable and safe electrical service under this Act.

To ensure that these findings and prerequisites for reliable and safe electrical service continue to prevail, each alternative retail electric supplier, electric utility, and contractors and subcontractors performing work on behalf of an electric utility or alternative retail electric supplier must demonstrate the competence of their respective employees to work on the distribution system.

The knowledge, skill, training, experience, and competence levels to be demonstrated shall be consistent with those required of or by the electric utilities in this State as of January 1, 2007, with respect to their employees and employees of contractors or subcontractors performing work on their behalf. Nothing in this Section shall prohibit an electric utility from establishing knowledge, skill, training, experience, and competence levels greater than those required as of January 1, 2007.

An adequate demonstration of requisite knowledge, skill, training, experience, and competence shall include, at a minimum, completion or current participation and ultimate completion by the employee of an accredited or otherwise recognized apprenticeship program for the particular craft, trade or skill, or specified and several years of employment performing a particular work function that is utilized by an electric utility.

Notwithstanding any law, tariff, Commission rule, order, or decision to the contrary, the Commission shall have an affirmative statutory obligation to ensure that an electric utility is employing employees, contractors, and subcontractors with employees who meet the requirements of subsection (a) of this Section when installing, constructing, operating, and maintaining generation, transmission, or distribution facilities and equipment within this State pursuant to any provision in this Act or any Commission order, rule, or decision.

For purposes of this Section, "distribution facilities and equipment" means any and all of the facilities and equipment, including, but not limited to, substations, distribution feeder circuits, switches, meters, protective equipment, primary circuits, distribution transformers, line extensions and service extensions both above or below ground, conduit, risers, elbows, transformer pads, junction boxes, manholes, pedestals, conductors, and all associated fittings that connect the transmission or distribution system to either the weatherhead on the retail customer's building or other structure for above ground service or to the terminals on the meter base of the retail customer's building or other structure for below ground service.

To implement this requirement for alternative retail electric suppliers, the Commission, in determining that an applicant meets the standards for certification as an alternative retail electric supplier, shall require the applicant to demonstrate (i) that the applicant is licensed to do business, and bonded, in the State of Illinois; and (ii) that the employees of the applicant that will be installing, operating, and maintaining generation, transmission, or distribution facilities within this State, or any entity with which the applicant has contracted to perform those functions within this State, have the requisite knowledge, skills, training, experience, and competence to perform those functions in a safe and responsible manner in order to provide safe and reliable service, in accordance with the criteria stated above.

(b) The General Assembly finds, based on experience in other industries that have undergone similar transitions, that the introduction of competition into the State's electric utility industry may result in workforce reductions by electric utilities which may adversely affect persons who have been employed by this State's electric utilities in functions important to the public convenience and welfare. The General Assembly further finds that the impacts on employees and their communities of any necessary reductions in the utility workforce directly caused by this restructuring of the electric industry shall be mitigated to the extent practicable through such means as offers of voluntary severance, retraining, early retirement, outplacement and related benefits. Therefore, before any such reduction in the workforce during the transition period, an electric utility shall present to its employees or their representatives a workforce reduction plan outlining the means by which the electric utility intends to mitigate the impact of such workforce reduction on its employees.

(c) In the event of a sale, purchase, or any other transfer of ownership during the mandatory transition period of one or more Illinois divisions or business units, and/or generating stations or generating units, of an electric utility, the electric utility's contract and/or agreements with the acquiring entity or persons shall require that the entity or persons hire a sufficient number of non-supervisory employees to operate and maintain the station, division or unit by initially making offers of employment to the non-supervisory workforce of the electric utility's division, business unit, generating station and/or generating unit at no less than the wage rates, and substantially equivalent fringe benefits and terms and conditions of employment that are in effect at the time of transfer of ownership of said division, business unit, generating station, and/or generating units; and said wage rates and substantially equivalent fringe benefits and terms and conditions of employment shall continue for at least 30 months from the time of said transfer of ownership unless the parties mutually agree to different terms and conditions of employment within that 30-month period. The utility shall offer a transition plan to those employees who are not offered jobs by the acquiring entity because that entity has a need for fewer workers. If there is litigation concerning the sale, or other transfer of ownership of the electric utility's divisions, business units, generating station, or generating units, the 30-month period will begin on the date the acquiring entity or persons take control or management of the divisions, business units, generating station or generating units of the electric utility.

(d) If a utility transfers ownership during the mandatory transition period of one or more Illinois divisions, business units, generating stations or generating units of an electric utility to a majority-owned subsidiary, that subsidiary shall continue to employ the utility's employees who were employed by the utility at such division, business unit or generating station at the time of the transfer under the same terms and conditions of employment as those employees enjoyed at the time of the transfer. If ownership of the subsidiary is subsequently sold or transferred to a third party during the transition period, the transition provisions outlined in subsection (c) shall apply.

(e) The plant transfer provisions set forth above shall not apply to any generating station which was the subject of a sales agreement entered into before January 1, 1997.

(Source: P.A. 97-616, eff. 10-26-11; 97-646, eff. 12-30-11.)

(220 ILCS 5/16-128A)

Sec. 16-128A. Certification of installers, maintainers, or repairers.

(a) Within 18 months of the effective date of this amendatory Act of the 97th General Assembly, the Commission shall adopt rules, including emergency rules, establishing certification requirements ensuring that entities installing distributed generation facilities are in compliance with the requirements of subsection (a) of Section 16-128 of this Act.

For purposes of this Section, the phrase "entities installing distributed generation facilities" shall include, but not be limited to, all entities that are exempt from the definition of "alternative retail electric supplier" under item (v) of Section 16-102 of this Act. For purposes of this Section, the phrase "self-installer" means an individual who (i) leases or purchases a cogeneration facility for his or her own personal use and (ii) installs such cogeneration or self-generation facility on his or her own premises without the assistance of any other person.

(b) In addition to any authority granted to the Commission under this Act, the Commission is also authorized to: (1) determine which entities are subject to certification under this Section; (2) impose reasonable certification fees and penalties; (3) adopt disciplinary procedures; (4) investigate any and all activities subject to this Section, including violations thereof; (5) adopt procedures to issue or renew, or to refuse to issue or renew, a certification or to revoke, suspend, place on probation, reprimand, or otherwise discipline a certified entity under this Act or take other enforcement action against an entity subject to this Section; and (6) prescribe forms to be issued for the administration and enforcement of this Section.

(c) No electric utility shall provide a retail customer with net metering service related to interconnection of that customer's distributed generation facility unless the customer provides the electric utility with (i) a certification that the customer installing the distributed generation facility was a self-installer or (ii) evidence that the distributed generation facility was installed by an entity certified under this Section that is also in good standing with the Commission. For purposes of this subsection, a retail customer includes that customer's employees, officers, and agents. An electric utility shall file a tariff or tariffs with the Commission setting forth the documentation, as specified by Commission rule, that a retail customer must provide to an electric utility. The provisions of this subsection (c) shall apply on or after the effective date of the Commission's rules prescribed pursuant to subsection (a) of this Section.

(d) Within 180 days after the effective date of this amendatory Act of the 97th General Assembly, the Commission shall initiate a rulemaking proceeding to establish certification requirements that shall be applicable to persons or entities that install, maintain, or repair electric vehicle charging stations. The notification and certification requirements of this Section shall only be applicable to individuals or entities that perform work on or within an electric vehicle charging station, including, but not limited to, connection of power to an electric vehicle charging station.

For the purposes of this Section "electric vehicle charging station" means any facility or equipment that is used to charge a battery or other energy storage device of an electric vehicle.

Rules regulating the installation, maintenance, or repair of electric vehicle charging stations, in which the Commission may establish separate requirements based upon the characteristics of electric vehicle charging stations, so long as it is in accordance with the requirements of subsection (a) of Section 16-128 and Section 16-128A of this Act, shall:

(1) establish a certification process for persons or entities that install, maintain, or repair of electric vehicle charging stations;

(2) require persons or entities that install, maintain, or repair electric vehicle stations to be certified to do business and to be bonded in the State;

(3) ensure that persons or entities that install, maintain, or repair electric vehicle charging stations have the requisite knowledge, skills, training, experience, and competence to perform functions in a safe and reliable manner as required under subsection (a) of Section 16-128 of this Act;

(4) impose reasonable certification fees and penalties on persons or entities that install, maintain, or repair of electric vehicle charging stations for noncompliance of the rules adopted under this subsection;

(5) ensure that all persons or entities that install, maintain, or repair electric vehicle charging stations conform to applicable building and electrical codes;

(6) ensure that all electric vehicle charging stations meet recognized industry standards as the Commission deems appropriate, such as the National Electric Code (NEC) and standards developed or created by the Institute of Electrical and Electronics Engineers (IEEE), the Electric Power Research Institute (EPRI), the Detroit Edison Institute (DTE), the Underwriters Laboratory (UL), the Society of Automotive Engineers (SAE), and the National Institute of Standards and Technology (NIST);

(7) include any additional requirements that the Commission deems reasonable to ensure that persons or entities that install, maintain, or repair electric vehicle charging stations meet adequate training, financial, and competency requirements;

(8) ensure that the obligations required under this Section and subsection (a) of Section 16-128 of this Act are met prior to the interconnection of any electric vehicle charging station;

(9) ensure electric vehicle charging stations installed by a self-installer are not used for any commercial purpose;

(10) establish an inspection procedure for the conversion of electric vehicle charging stations installed by a self-installer if it is determined that the self-installed electric vehicle charging station is being used for commercial purposes;

(11) establish the requirement that all persons or entities that install electric vehicle charging stations shall notify the servicing electric utility in writing of plans to install an electric vehicle charging station and shall notify the servicing electric utility in writing when installation is complete;

(12) ensure that all persons or entities that install, maintain, or repair electric vehicle charging stations obtain certificates of insurance in sufficient amounts and coverages that the Commission so determines and, if necessary as determined by the Commission, names the affected public utility as an additional insured; and

(13) identify and determine the training or other programs by which persons or entities may obtain the requisite training, skills, or experience necessary to achieve and maintain compliance with the requirements set forth in this subsection and subsection (a) of Section 16-128 to install, maintain, or repair electric vehicle charging stations.

Within 18 months after the effective date of this amendatory Act of the 97th General Assembly, the Commission shall adopt rules, and may, if it deems necessary, adopt emergency rules, for the installation, maintenance, or repair of electric vehicle charging stations.

All retail customers who own, maintain, or repair an electric vehicle charging station shall provide the servicing electric utility (i) a certification that the customer installing the electric vehicle charging station was a self-installer or (ii) evidence that the electric vehicle charging station was installed by an entity certified under this subsection (d) that is also in good standing with the Commission. For purposes of this subsection (d), a retail customer includes that retail customer's employees, officers, and agents. If the electric vehicle charging station was not installed by a self-installer, then the person or entity that plans to install the electric vehicle charging station shall provide notice to the servicing electric utility prior to installation and when installation is complete and provide any other information required by the Commission's rules established under subsection (d) of this Section. An electric utility shall file a tariff or tariffs with the Commission setting forth the documentation, as specified by Commission rule, that a retail customer who owns, uses, operates, or maintains an electric vehicle charging station must provide to an electric utility.

For the purposes of this subsection, an electric vehicle charging station shall constitute a distribution facility or equipment as that term is used in subsection (a) of Section 16-128 of this Act. The phrase "self-installer" means an individual who (i) leases or purchases an electric vehicle charging station for his or her own personal use and (ii) installs an electric vehicle charging station on his or her own premises without the assistance of any other person.

(e) Fees and penalties collected under this Section shall be deposited into the Public Utility Fund and used to fund the Commission's compliance with the obligations imposed by this Section.

(f) The rules established under subsection (d) of this Section shall specify the initial dates for compliance with the rules.

(g) Within 18 months of the effective date of this amendatory Act of the 99th General Assembly, the Commission shall adopt rules, including emergency rules, establishing a process for entities installing a new utility-scale solar project to certify compliance with the requirements of this Section. For purposes of this Section, the phrase "entities installing a new utility-scale solar project" shall include, but is not limited to, any entity installing new photovoltaic projects as such terms are defined in subsection (c) of Section 1-75 of the Illinois Power Agency Act.

The process shall include an option to complete the certification electronically by completing forms on-line. An entity installing a new utility-scale solar project shall be permitted to complete certification after the subject work has been completed. The Commission shall maintain on its website a list of entities installing new utility-scale solar projects measures that have successfully completed the certification process.

(h) In addition to any authority granted to the Commission under this Act, the Commission is also authorized to: (1) determine which entities are subject to certification under subsection (g) of this Section; (2) impose reasonable certification fees and penalties; (3) adopt disciplinary procedures; (4) investigate any and all activities subject to subsection (g) or this subsection (h) of this Section, including violations thereof; (5) adopt procedures to issue or renew, or to refuse to issue or renew, a certification or to revoke, suspend, place on probation, reprimand, or otherwise discipline a certified entity under subsection (g) of this Section or take other enforcement action against an entity subject to subsection (g) or this subsection (h) of this Section; (6) prescribe forms to be issued for the administration and enforcement of subsection (g) and this subsection (h) of this Section; and (7) establish requirements to ensure that entities installing a new photovoltaic project have the requisite knowledge, skills, training, experience, and competence to perform in a safe and reliable manner as required by subsection (a) of Section 16-128 of this Act.

(i) The certification of persons or entities that install, maintain, or repair new photovoltaic projects, distributed generation facilities, and electric vehicle charging stations as set forth in this Section is an exclusive power and function of the State. A home rule unit or other units of local government authority may subject persons or entities that install, maintain, or repair new photovoltaic projects, distributed generation facilities, or electric vehicle charging stations as set forth in this Section to any applicable local licensing, siting, and permitting requirements otherwise permitted under law so long as only Commission-certified persons or entities are authorized to install, maintain, or repair new photovoltaic projects, distributed generation facilities, or electric vehicle charging stations. This Section is a limitation under subsection (h) of Section 6 of Article VII of the Illinois Constitution on the exercise by home rule units of powers and functions exclusively exercised by the State.

(Source: P.A. 99-906, eff. 6-1-17; 100-16, eff. 6-30-17.)

(220 ILCS 5/16-128B)

Sec. 16-128B. Qualified energy efficiency installers.

(a) Within 18 months after the effective date of this amendatory Act of the 99th General Assembly, the Commission shall adopt rules, including emergency rules, establishing a process for entities installing energy efficiency measures to certify compliance with the requirements of this Section.

The process shall include an option to complete the certification electronically by completing forms on-line. An entity installing energy efficiency measures shall be permitted to complete the certification after the subject work has been completed.

The Commission shall maintain on its website a list of entities installing energy efficiency measures that have successfully completed the certification process.

(b) In addition to any authority granted to the Commission under this Act, the Commission may:

(1) determine which entities are subject to certification under this Section;

(2) impose reasonable certification fees and penalties;

(3) adopt disciplinary procedures;

(4) investigate any and all activities subject to this Section, including violations thereof;

(5) adopt procedures to issue or renew, or to refuse to issue or renew, a certification or to revoke, suspend, place on probation, reprimand, or otherwise discipline a certified entity under this Act or take other enforcement action against an entity subject to this Section; and

(6) prescribe forms to be issued for the administration and enforcement of this Section.

(c) An electric utility may not provide a retail customer with a rebate or other energy efficiency incentive for a measure that exceeds a minimal amount determined by the Commission unless the customer provides the electric utility with (1) a certification that the person installing the energy efficiency measure was a self-installer; or (2) evidence that the energy efficiency measure was installed by an entity certified under this Section that is also in good standing with the Commission.

(d) The Commission shall:

(1) require entities installing energy efficiency measures to be certified to do business and to be bonded in this State;

(2) ensure that entities installing energy efficiency measures have the requisite knowledge, skill, training, experience, and competence to perform functions in a safe and reliable manner as required under subsection (a) of Section 16-128 of this Act;

(3) ensure that entities installing energy efficiency measures conform to applicable building and electrical codes;

(4) ensure that all entities installing energy efficiency measures meet recognized industry standards as the Commission deems appropriate;

(5) include any additional requirements that the Commission deems reasonable to ensure that entities installing energy efficiency measures meet adequate training, financial, and competency requirements;

(6) ensure that all entities installing energy efficiency measures obtain certificates of insurance in sufficient amounts and coverages that the Commission so determines; and

(7) identify and determine the training or other programs by which persons or entities may obtain the requisite training, skill, or experience necessary to achieve and maintain compliance with the requirements of this Section.

(e) Fees and penalties collected under this Section shall be deposited into the Public Utility Fund and used to fund the Commission's compliance with the obligations imposed by this Section.

(f) The rules adopted under this Section shall specify the initial dates for compliance with the rules.

(g) For purposes of this Section, entities installing energy efficiency measures shall endeavor to support the diversity goals of this State by attracting, developing, retaining, and providing opportunities to employees of all backgrounds and by supporting female-owned, minority-owned, veteran-owned, and small businesses.

(Source: P.A. 99-906, eff. 6-1-17.)

(220 ILCS 5/16-129)

Sec. 16-129. Existing contracts not affected. Nothing in this Article XVI shall affect the right of an electric utility to continue to provide, or the right of the customer to continue to receive, service pursuant to a contract for electric service between the electric utility and the customer, in accordance with the prices, terms and conditions provided for in that contract. Either the electric utility or the customer may require compliance with the prices, terms and conditions of such contract.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/16-130)

Sec. 16-130. Annual reports.

(a) The General Assembly finds that it is necessary to have reliable and accurate information regarding the transition to a competitive electric industry. In addition to the annual report requirements pursuant to Section 5-109 of this Act, each electric utility shall file with the Commission a report on the following topics in accordance with the schedule set forth in subsection (b) of this Section:

(1) Data on each customer class of the electric utility in which delivery services have been elected, including:

(A) number of retail customers in each class that have elected delivery service;

(B) kilowatt hours consumed by the customers described in subparagraph (A);

(C) revenue loss experienced by the utility as a result of customers electing delivery services or market-based prices as compared to continued service under otherwise applicable tariffed rates;

(D) total amount of funds collected from each customer class pursuant to the transition charges authorized in Section 16-108;

(E) such other information as the Commission may by rule require.

(2) A description of any steps taken by the electric utility to mitigate and reduce its costs, including both a detailed description of steps taken during the preceding calendar year and a summary of steps taken since December 16, 1997 (the effective date of Public Act 90-561), and including, to the extent practicable, quantification of the costs mitigated or reduced by specific actions taken by the electric utility.

(3) A description of actions taken under Sections 5-104, 7-204, 9-220, and 16-111 of this Act. This information shall include, but not be limited to:

(A) a description of the actions taken;

(B) the effective date of the action;

(C) the annual savings or additional charges realized by customers from actions taken, by customer class and total for each year;

(D) the accumulated impact on customers by customer class and total; and

(E) a summary of the method used to quantify the impact on customers.

(4) A summary of the electric utility's use of transitional funding instruments, including a description of the electric utility's use of the proceeds of any transitional funding instruments it has issued in accordance with Article XVIII of this Act.

(5) Kilowatt-hours consumed in the twelve months ending December 31, 1996 (which kilowatt-hours are hereby referred to as "base year sales") by customer class multiplied by the revenue per kilowatt hour, adjusted to remove charges added to customers' bills pursuant to Sections 9-221 and 9-222 of this Act, during the twelve months ending December 31, 1996, adjusted for the reductions required by subsection (b) of Section 16-111 and the mitigation factors contained in Section 16-102. This amount shall be stated for: (i) each calendar year preceding the year in which a report is required to be submitted pursuant to subsection (b); and (ii) as a cumulative total of all calendar years beginning with 1998 and ending with the calendar year preceding the year in which a report is required to be submitted pursuant to subsection (b).

(6) Calculations identical to those required by subparagraph (5) except that base year sales shall be adjusted for growth in the electric utility's service territory, in addition to the other adjustments specified by the first sentence of subparagraph (5).

(7) The electric utility's total revenue and net income for each calendar year beginning with 1997 through the calendar year preceding the year in which a report is required to be submitted pursuant to subsection (b) as reported in the electric utility's Form 1 report to the Federal Energy Regulatory Commission.

(8) Any consideration in excess of the net book cost as of December 16, 1997 (the effective date of Public Act 90-561) received by the electric utility during the year from a sale made subsequent to December 16, 1997 (the effective date of Public Act 90-561) to a non-affiliated third party of any generating plant that was owned by the electric utility on December 16, 1997 (the effective date of Public Act 90-561).

(9) Any consideration received by the electric utility from sales or transfers during the year to an affiliated interest of generating plant, or other plant that represents an investment of $25,000,000 or more in terms of total depreciated original cost, which generating or other plant were owned by the electric utility prior to December 16, 1997 (the effective date of Public Act 90-561).

(10) Any consideration received by an affiliated interest of an electric utility from sales or transfers during the year to a non-affiliated third party of generating plant, but only if: (i) the electric utility had previously sold or transferred such plant to the affiliated interest subsequent to December 16, 1997 (the effective date of Public Act 90-561); (ii) the affiliated interest sells or transfers such plant to a non-affiliated third party prior to December 31, 2006; and (iii) the affiliated interest receives consideration for the sale or transfer of such plant to the non-affiliated third party in an amount greater than the cost or price at which such plant was sold or transferred to the affiliated interest by the electric utility.

(11) A summary account of those expenditures made for projects, programs, and improvements relating to transmission and distribution including, without limitation, infrastructure expansion, repair and replacement, capital investments, operations and maintenance, and vegetation management, pursuant to a written commitment made under subsection (k) of Section 16-111.

(b) The information required by subsection (a) shall be filed by each electric utility on or before March 1 of each year 1999 through 2007 or through such additional years as the electric utility is collecting transition charges pursuant to subsection (f) of Section 16-108, for the previous calendar year. The information required by subparagraph (6) of subsection (a) for calendar year 1997 shall be submitted by the electric utility on or before March 1, 1999.

(c) On or before May 15 of each year 1999 through 2006 or through such additional years as the electric utility is collecting transition charges pursuant to subsection (f) of Section 16-108, the Commission shall submit a report to the General Assembly which summarizes the information provided by each electric utility under this Section; provided, however, that proprietary or confidential information shall not be publicly disclosed.

(Source: P.A. 102-558, eff. 8-20-21.)

(220 ILCS 5/16-135)

Sec. 16-135. Energy Storage Program.

(a) The Illinois General Assembly hereby finds and declares that:

(1) Energy storage systems provide opportunities to:

(A) reduce costs to ratepayers directly or indirectly by avoiding or deferring the need for investment in new generation and for upgrades to systems for the transmission and distribution of electricity;

(B) reduce the use of fossil fuels for meeting demand during peak load periods;

(C) provide ancillary services such as frequency response, load following, and voltage support;

(D) assist electric utilities with integrating sources of renewable energy into the grid for the transmission and distribution of electricity, and with maintaining grid stability;

(E) support diversification of energy resources;

(F) enhance the resilience and reliability of the electric grid; and

(G) reduce greenhouse gas emissions and other air pollutants resulting from power generation, thereby minimizing public health impacts that result from power generation.

(2) There are significant barriers to obtaining the benefits of energy storage systems, including inadequate valuation of the services that energy storage can provide to the grid and the public.

(3) It is in the public interest to:

(A) develop a robust competitive market for existing and new providers of energy storage systems in order to leverage Illinois' position as a leader in advanced energy and to capture the potential for economic development;

(B) implement targets and programs to achieve deployment of energy storage systems; and

(C) modernize distributed energy resource programs and interconnection standards to lower costs and efficiently deploy energy storage systems in order to increase economic development and job creation within the state's clean energy economy.

(b) In this Section:

"Energy storage peak standard" means a percentage of annual retail electricity sales during peak hours that an electric utility must derive from electricity discharged from eligible energy storage systems.

"Deployment" means the installation of energy storage systems through a variety of mechanisms, including utility procurement, customer installation, or other processes.

"Electric utility" has the same meaning as provided in Section 16-102 of this Act.

"Energy storage system" means a technology that is capable of absorbing zero-carbon energy, storing it for a period of time, and redelivering that energy after it has been stored in order to provide direct or indirect benefits to the broader electricity system. The term includes, but is not limited to, electrochemical, thermal, and electromechanical technologies.

"Nonwires alternatives solicitation" means a utility solicitation for third-party-owned or utility-owned distributed energy resources that uses nontraditional solutions to defer or replace planned investment on the distribution or transmission system.

"Total peak demand" means the highest hourly electricity demand for an electric utility in a given year, measured in megawatts, from all of the electric utility's customers of distribution service.

(c) The Commission, in consultation with the Illinois Power Agency, shall initiate a proceeding to examine specific programs, mechanisms, and policies that could support the deployment of energy storage systems. The Illinois Commerce Commission shall engage a broad group of Illinois stakeholders, including electric utilities, the energy storage industry, the renewable energy industry, and others to inform the proceeding. The proceeding must, at minimum:

(1) develop a framework to identify and measure the potential costs, benefits, that deployment of energy storage could produce, as well as barriers to realizing such benefits, including, but not limited to:

(A) avoided cost and deferred investments in generation, transmission, and distribution facilities;

(B) reduced ancillary services costs;

(C) reduced transmission and distribution congestion;

(D) lower peak power costs and reduced capacity costs;

(E) reduced costs for emergency power supplies during outages;

(F) reduced curtailment of renewable energy generators;

(G) reduced greenhouse gas emissions and other criteria air pollutants;

(H) increased grid hosting capacity of renewable energy generators that produce energy on an intermittent basis;

(I) increased reliability and resilience of the electric grid;

(J) reduced line losses;

(K) increased resource diversification;

(L) increased economic development;

(2) analyze and estimate:

(A) the impact on the system's ability to integrate renewable resources;

(B) the benefits of addition of storage at specific locations, such as at existing peaking units or locations on the grid close to large load centers;

(C) the impact on grid reliability and power quality; and

(D) the effect on retail electric rates and supply rates over the useful life of a given energy storage system; and

(3) evaluate and identify cost-effective policies and programs to support the deployment of energy storage systems, including, but not limited to:

(A) incentive programs;

(B) energy storage peak standards;

(C) nonwires alternative solicitation;

(D) peak demand reduction programs for behind-the-meter storage for all customer classes;

(E) value of distributed energy resources programs;

(F) tax incentives;

(G) time-varying rates;

(H) updating of interconnection processes and metering standards; and

(I) procurement by the Illinois Power Agency of energy storage resources.

(d) The Commission shall, no later than May 31, 2022, submit to the General Assembly and the Governor any recommendations for additional legislative, regulatory, or executive actions based on the findings of the proceeding.

(e) At the conclusion of the proceeding required under subsection (c), the Commission shall consider and recommend to the Governor and General Assembly energy storage deployment targets, if any, for each electric utility that serves more than 200,000 customers to be achieved by December 31, 2032, including recommended interim targets.

(f) In setting recommendations for energy storage deployment targets, the Commission shall:

(1) take into account the costs and benefits of procuring energy storage according to the framework developed in the proceeding under subsection (c);

(2) consider establishing specific subcategories of deployment of systems by point of interconnection or application.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/Art. XVII heading) ARTICLE XVII. ELECTRIC COOPERATIVES AND MUNICIPAL SYSTEMS

(220 ILCS 5/17-100)

Sec. 17-100. Exemption from provisions of this amendatory Act of 1997. Electric cooperatives, as defined in Section 3.4 of the Electric Supplier Act, and public utilities that are owned and operated by any political subdivision, or municipal corporation of this State, or owned by such an entity and operated by any lessee or any operating agent thereof, hereinafter referred to as municipal systems, shall not be subject to the provisions of this amendatory Act of 1997, except as hereinafter provided in this Article XVII.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/17-200)

Sec. 17-200. Election to provide existing or future customers access to alternative retail electric suppliers.

(a) An electric cooperative or municipal system each may, by appropriate action and at the sole discretion of the governing body of each, from time to time make one or more elections to cause one or more of the existing or future customers of each respective system to be eligible to take service from an alternative retail electric supplier for a specified period of time. Provided that, and subject to their authority to serve customers pursuant to the Electric Supplier Act with respect to electric cooperatives and pursuant to the Illinois Municipal Code with respect to municipal systems, each shall continue to provide exclusive distribution facilities for any existing and future customers that the electric cooperative or municipal system are now or in the future otherwise entitled to serve and which customers are now or in the future receiving service provided by an alternative retail electric supplier.

(b) Notification of election to provide existing or future customers access to alternative retail electric suppliers. The election by an electric cooperative or municipal system authorizing access to alternative retail electric suppliers for existing or future customers shall be made by filing notice thereof with the Commission and shall be made effective only by such filing.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/17-300)

Sec. 17-300. Election to be an alternative retail electric supplier.

(a) An electric cooperative or municipal system may, by appropriate action, and at the sole discretion of the governing body of each, make an election to become an alternative retail electric supplier. A generation and transmission electric cooperative may not, as an alternative retail electric supplier, serve any present or future retail customers of a distribution electric cooperative not a member of that generation and transmission electric cooperative unless at least 30% of the total number of meters of the generation and transmission electric cooperative's member-cooperatives are eligible to obtain electric power and energy from an alternative retail electric supplier other than the generation and transmission electric cooperative or an electric utility due to member-cooperative elections pursuant to either Section 17-200 or 17-300.

(b) Commission authority over an electric cooperative or municipal system electing to be an alternative retail electric supplier. An electric cooperative or municipal system electing to be an alternative retail electric supplier shall provide those services in accordance with Sections 16-115A and 16-115B of this Act, to the extent that these Sections have application to the services being offered by the electric cooperative or municipal system as an alternative retail electric supplier. In no case shall these provisions apply to the existing or future customers taking delivery services from an electric cooperative or municipal system pursuant to their respective authority under the Electric Supplier Act or the Illinois Municipal Code.

(c) Notification of election to be an alternative retail electric supplier. Upon filing notice of intent by an electric cooperative or a municipal system to become an alternative retail electric supplier, the Commission shall issue within 45 days a certificate of service authority for the entire State or for a specified geographic area of the State, as specified in the notice. Issuance of a certificate of service authority shall constitute compliance with Section 16-115 of this Act.

(d) Delivery services provided by electric cooperatives or municipal systems. Municipal systems or electric cooperatives making an election under this Section shall be required to provide delivery services on their respective systems to the electric utility or utilities in whose service area or areas the proposed service will be offered. Such required delivery services to be provided by the electric cooperatives and municipal systems shall be reasonably comparable to the delivery services provided to the electric cooperative's and municipal system's own customers.

(e) Exclusive authority over distribution facilities. Provided that, and subject to their authority to serve customers pursuant to the Electric Supplier Act with respect to electric cooperatives and pursuant to the Illinois Municipal Code with respect to municipal systems, each shall continue to provide the exclusive distribution facilities for any existing and future customers that the electric cooperative or municipal system is now or in the future otherwise entitled to serve, and which customers are now or in the future receiving service provided by an alternative retail electric supplier.

(Source: P.A. 90-561, eff. 12-16-97; 90-624, eff. 7-10-98.)

(220 ILCS 5/17-400)

Sec. 17-400. Conditions prohibiting municipal system participation. At no time shall a municipal system make an election under Sections 17-200 or 17-300 of this Article if such election places at risk:

(1) Any status held by the municipal system or municipal corporation or political subdivision which provides exemption from State or federal tax statutes; or

(2) Any debt, credit instrument or other contractual financial obligation held by, or on behalf of the municipal system which was entered into under an exemption from State or federal tax statutes.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/17-500)

Sec. 17-500. Jurisdiction. Except as provided in the Electric Supplier Act, the Illinois Municipal Code, and this Article XVII, the Commission, or any other agency or subdivision thereof of the State of Illinois or any private entity shall have no jurisdiction over any electric cooperative or municipal system regardless of whether any election or elections as provided for herein have been made, and all control regarding an electric cooperative or municipal system shall be vested in the electric cooperative's board of directors or trustees or the applicable governing body of the municipal system.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/17-600)

Sec. 17-600. Rights of electric cooperatives and municipal systems in conflict herewith. Except as expressly provided for herein, this Article XVII shall not be construed to conflict with the rights of an electric cooperative or a municipal system as declared in the Electric Supplier Act or as set forth in the Illinois Municipal Code or the public policy against duplication of facilities as set forth therein.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/17-700)

Sec. 17-700. Right to create municipal utility unaffected. Nothing in this amendatory Act of 1997 shall limit the right of a municipality to form a municipal utility in accordance with Article 11, Division 117 of the Illinois Municipal Code and the provisions of this Article XVII shall apply to any municipal utility formed after the effective date of this amendatory Act of 1997.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/17-800)

Sec. 17-800. (Repealed).

(Source: P.A. 95-311, eff. 1-1-08. Repealed by P.A. 96-176, eff. 1-1-10.)

(220 ILCS 5/17-900)

Sec. 17-900. Customer self-generation of electricity.

(a) The General Assembly finds and declares that municipal systems and electric cooperatives shall continue to be governed by their respective governing bodies, but that such governing bodies should recognize and implement policies to provide the opportunity for their residential and small commercial customers who wish to self-generate electricity and for reasonable credits to customers for excess electricity, balanced against the rights of the other non-self-generating customers. This includes creating consistent, fair policies that are accessible to all customers and transparent, fair processes for raising and addressing any concerns.

(b) Customers have the right to install renewable generating facilities to be located on the customer's premises or customer's side of the billing meter and that are intended primarily to offset the customer's own electrical requirements and produce, consume, and store their own renewable energy without discriminatory repercussions from an electric cooperative or municipal system. This includes a customer's rights to:

(1) generate, consume, and deliver excess renewable energy to the distribution grid and reduce his or her use of electricity obtained from the grid;

(2) use technology to store energy at his or her residence;

(3) interconnect his or her electrical system that generates renewable energy, stores energy, or any combination thereof, with the electricity meter on the customer's premises that is provided by an electric cooperative or municipal system:

(A) in a timely manner;

(B) in accordance with requirements established by the electric cooperative or municipal utility to ensure the safety of utility workers; and

(C) after providing written notice to the electric cooperative or municipal utility system providing service in the service territory, installing a nomenclature plate on the electrical meter panel and meeting all applicable State and local safety and electrical code requirements associated with installing a parallel distributed generation system; and

(4) receive fair credit for excess energy delivered to the distribution grid.

(c) The policies of municipal systems and electric cooperatives regarding self-generation and credits for excess electricity may reasonably differ from those required of other entities by Article XVI of the Public Utilities Act or other Acts. The credits must recognize the value of self-generation to the distribution grid and benefits to other customers.

(d) Within 180 days after this amendatory Act of the 102nd General Assembly, each electric cooperative and municipal system shall update its policies for the interconnection and fair crediting of customer self-generation and storage if necessary, to comply with the standards of subsection (b) of this Section. Each electric cooperative and municipal system shall post its updated policies to a public-facing area of its website.

(e) An electric cooperative or municipal system customer who produces, consumes, and stores his or her own renewable energy shall not face discriminatory rate design, fees or charges, treatment, or excessive compliance requirements that would unreasonably affect that customer's right to self-generate electricity as provided for in this Section.

(f) An electric cooperative or municipal utility system customer shall have a right to appeal any decision related to self-generation and storage that violates these rights to self-generation and non-discrimination pursuant to the provisions of this Section through a complaint under the Administrative Review Law or similar legal process.

(Source: P.A. 102-662, eff. 9-15-21.)

(220 ILCS 5/Art. XVIII heading) ARTICLE XVIII. ELECTRIC UTILITY TRANSITIONAL FUNDING LAW

(220 ILCS 5/18-101)

Sec. 18-101. Short title and applicability. This Article may be cited as the Electric Utility Transitional Funding Law of 1997 and shall apply to electric utilities as defined in this Article.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/18-102)

Sec. 18-102. Definitions. For the purposes of this Article the following terms shall be defined as set forth in this Section. Terms defined in Article XVI shall have the same meanings in this Article.

"Assignee" means any party, other than an electric utility or grantee, to which an interest in intangible transition property shall have been assigned, sold or transferred. The term "assignee" includes any corporation, public authority, trust, financing vehicle, partnership, limited liability company or other entity.

"Grantee" means any party, other than an electric utility or an assignee which acquires its interest from an electric utility, to whom or for whose benefit the Commission shall create, establish and grant rights in, to and under intangible transition property. The term "grantee" includes any corporation, public authority, trust, financing vehicle, partnership, limited liability company or other entity.

"Grantee instruments" means (a) any instruments, documents, notes, debentures, bonds or other evidences of indebtedness evidencing any contractual right to receive the payment of money from a grantee or (b) any certificates of participation, certificates of beneficial interest or other instruments evidencing a beneficial or ownership interest in a grantee or in intangible transition property of such grantee which are (i) issued (A) by or on behalf of a grantee pursuant to a transitional funding order and (B) pursuant to an executed indenture, pooling agreement, security agreement or other similar agreement of such grantee creating a security interest, ownership interest or other beneficial interest in intangible transition property and (ii) payable solely from proceeds of intangible transition property, including amounts received with respect to the related instrument funding charges.

"Holder" means any holder of transitional funding instruments, including a trustee, collateral agent, nominee or other such party acting for the benefit of such a holder.

"Instrument funding charge" means a non-bypassable charge expressed in cents per kilowatt-hour authorized in a transitional funding order to be applied and invoiced to each retail customer, class of retail customers of an electric utility or other person or group of persons obligated to pay any base rates, transition charges or other rates for tariffed services from which such instrument funding charge has been deducted and stated separately pursuant to subsection (j) of Section 18-104.

"Intangible transition property" means the right, title, and interest of an electric utility or grantee or assignee arising pursuant to a transitional funding order to impose and receive instrument funding charges, and all related revenues, collections, claims, payments, money, or proceeds thereof, including all right, title, and interest of an electric utility, grantee or assignee in, to, under and pursuant to such transitional funding order, whether or not such intangible transition property described above is characterized on the books of the electric utility as a regulatory asset or as a cost incurred by the electric utility or otherwise. Intangible transition property shall arise and exist only when, as, and to the extent that instrument funding charges are authorized in a transitional funding order that has become effective in accordance with this Article and shall thereafter continuously exist to the extent provided in the order.

"Issuer" means any party, other than an electric utility, which has issued transitional funding instruments. The term "issuer" includes any corporation, public authority, trust, financing vehicle, partnership, limited liability company or other entity.

"Transitional funding instruments" means any instruments, pass-through certificates, notes, debentures, certificates of participation, bonds, certificates of beneficial interest or other evidences of indebtedness or instruments evidencing a beneficial interest (i) which are issued by or on behalf of an electric utility or issuer pursuant to a transitional funding order, (ii) which are issued pursuant to an executed indenture, pooling agreement, security agreement or other similar agreement of an electric utility or issuer creating a security interest, ownership interest or other beneficial interest in intangible transition property or grantee instruments, if any, and (iii) the proceeds of which are to be used for the purposes set forth in subparagraph (1) of subsection (d) of Section 18-103 of this Article.

"Transitional funding order" means an order of the Commission issued in accordance with the provisions of this Article creating and establishing intangible transition property and the rights of any party therein and approving the sale, pledge, assignment or other transfer of intangible transition property and grantee instruments, if any, the issuance of transitional funding instruments and grantee instruments, if any, and the imposition and collection of instrument funding charges.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/18-103)

Sec. 18-103. Transitional funding orders.

(a) Notwithstanding any other provision of this Act or other law, the Commission is hereby authorized to issue transitional funding orders in accordance with the provisions of this Section, in order to facilitate (i) the issuance of transitional funding instruments by or on behalf of electric utilities or issuers and (ii) the issuance of grantee instruments by or on behalf of grantees.

(b) A transitional funding order may be issued by the Commission only upon the application of an electric utility and shall become effective in accordance with its terms only after such electric utility files with the Commission its written consent to all terms and conditions of such order. After the issuance of a transitional funding order, the electric utility or grantee shall retain sole discretion regarding whether to assign, sell, pledge or otherwise transfer intangible transition property and grantee instruments, if any, or to cause transitional funding instruments and grantee instruments, if any, to be issued, including the right to defer or postpone such assignment, sale, transfer, pledge or issuance or to change the terms thereof as allowed by such order.

(c) After the effective date of this amendatory Act of 1997, an electric utility may file any number of applications for transitional funding orders. Each application for a transitional funding order shall contain detailed information regarding the electric utility's proposal for (i) the assignment, sale, pledge or other transfer of, or the establishment, creation and granting of rights in and to, intangible transition property and grantee instruments, if any, (ii) the issuance of transitional funding instruments and grantee instruments, if any, (iii) the total dollar amount of intangible transition property to be created and the amount to be sold, pledged, assigned or otherwise transferred or granted hereunder (which amount may be in excess of the principal and interest payable on the transitional funding instruments and grantee instruments, if any, in order to provide for servicing costs and the funding or maintenance of debt service and other reserves, costs and fees as security to the holders of the transitional funding instruments and grantee instruments, if any), (iv) the amount of transitional funding instruments and grantee instruments, if any, to be issued, (v) the amount, expressed in cents per kilowatt-hour, of instrument funding charges to be collected from retail customers or other persons, (vi) the time to maturity for the transitional funding instruments and grantee instruments, if any, and (vii) the electric utility's planned use of the proceeds from the issuance of transitional funding instruments including the amounts allocated for the respective uses specified in subparagraph (1) of subsection (d) of Section 18-103 of this Article.

(d) The Commission shall, after proper notice, hold a hearing for the sole purpose of determining whether the application and requested transitional funding order are in compliance with this Article and shall complete its review of the application and issue its final transitional funding order by no later than 90 days after the filing of such application by the electric utility; provided, that, in contested cases where the public interest is in issue pursuant to subparagraph (1)(B) of this subsection (d) or pursuant to subsection (m) of Section 18-104, the Commission may complete its review and issue its final transitional funding order by no later than 120 days after the filing of such application. The order shall create and establish the proposed intangible transition property in the amount requested by the applicant and approve the proposed sale, pledge, assignment or other transfer of, or the establishment, creation and granting of rights in and to, intangible transition property and grantee instruments, if any, the proposed issuance of transitional funding instruments and grantee instruments, if any, and the proposed imposition and collection of the corresponding instrument funding charges, if the Commission finds that each of the following conditions are met:

(1) the electric utility will use the proceeds of the sale and issuance of the transitional funding instruments for one or more of the following purposes:

(A) to refinance debt or equity, or both, in a manner which the electric utility reasonably demonstrates will result in an overall reduction in its cost of capital, taking into account the costs of financing; provided, however, that any proceeds transferred to a parent company through a common stock repurchase transaction shall be used to retire publicly traded common stock of the parent company or to pay commercially reasonable transaction costs associated with such retirement;

(B) if the Commission finds that the sale or issuance of transitional funding instruments for the following purposes is in the public interest, then the following uses of proceeds: (i) to repay or retire fuel contracts or obligations related to nuclear spent fuel previously incurred by the electric utility in providing electric power or energy services prior to the effective date of this amendatory Act of 1997 or (ii) to pay any expenditures required to be undertaken by such electric utility by the provisions of Section 16-128 of this Act including labor severance costs and employee retraining costs;

(C) to fund debt service and other reserves, commercially reasonable costs and fees necessary or desirable in connection with the marketing of the transitional funding instruments and grantee instruments, if any;

(D) to pay for commercially reasonable costs associated with the issuance and collateralization of transitional funding instruments and grantee instruments, if any; and

(E) to pay for the commercially reasonable costs associated with the issuance of such transitional funding instruments, including the costs incurred since the effective date of this amendatory Act of 1997, or to be incurred, in connection with transactions to recapitalize, refinance or retire stock and/or debt, any associated taxes, and the costs incurred or to be incurred to obtain, collateralize, issue, service and administer transitional funding instruments and grantee instruments, including interest and other related fees, costs and charges;

provided, (i) that the transitional funding order shall require the electric utility to use (1) at least 80% of such proceeds for the purposes specified in subparagraphs (A) and (B) above and (2) no more than 20% of the maximum amount of such proceeds permitted under subparagraph (6)(B) of this subsection for purposes other than those specified in subparagraph (A) above; (ii) that the electric utility's use of such proceeds for the purposes specified in subparagraph (A) above shall not, as of the date of application of such proceeds, result in the common equity component of its capital structure, exclusive of the portion of its capital structure that consists of obligations representing transitional funding instruments or grantee instruments, being reduced below the lesser of (1) 40% and (2) the common equity percentage as of December 31, 1996 adjusted to reflect any write-off of assets or common equity implemented or required to be implemented as a result of this amendatory Act of 1997; and (iii) in no event shall the electric utility use the proceeds of the sale of grantee instruments or transitional funding instruments to repay or retire obligations incurred by any affiliate of the electric utility (other than in connection with any refinancing of grantee instruments or transitional funding instruments issued by such affiliate), without the consent of the Commission;

(2) the expected maturity date for the grantee instruments or the transitional funding instruments, and the final date on which the electric utility, grantee or assignee shall be entitled to charge and collect instrument funding charges, shall each be set to occur no later than December 31, 2008, subject to the provisions of subsections (l) and (m) of Section 18-104;

(3) the instrument funding charges authorized in such order will be deducted and stated separately from base rates and transition charges, and, where applicable, other rates for tariffed services, all as provided in subsection (j) of Section 18-104 and in a manner conforming to the allocation of the instrument funding charges implemented pursuant to subparagraph (4) of this subsection;

(4) the instrument funding charges authorized in such order shall have been allocated among classes of retail customers in accordance with percentage ratios determined by dividing the base rate revenue from each class by the electric utility's total base rate revenue for the 1996 calendar year;

(5) the issuance of the transitional funding instruments will not cause the rates for tariffed services to increase over the rates then in existence as adjusted for the rate decreases provided in subsection (b) of Section 16-111; and

(6) the aggregate principal amount of grantee instruments or, if such transitional funding order does not provide for the issuance of grantee instruments, transitional funding instruments, to be issued pursuant to such order, together with the aggregate amount of such instruments issued under any prior orders requested by such electric utility, shall not exceed:

(A) during the twelve-month period commencing August 1, 1998, an amount equal to 25% of the applicable electric utility's total capitalization, including both debt and equity, as of December 31, 1996, multiplied by the ratio of the electric utility's revenues from Illinois electric utility retail customers in the 1996 calendar year to its total electric retail revenues for such 1996 year; and

(B) thereafter, an amount equal to 50% of the applicable electric utility's total capitalization, including both debt and equity, as of December 31, 1996 multiplied by the ratio of the electric utility's revenues from Illinois electric utility retail customers in the 1996 calendar year to its total electric retail revenues for such 1996 year.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/18-104)

Sec. 18-104. Terms and provisions of transitional funding orders.

(a) Each transitional funding order shall create and establish intangible transition property in an amount not to exceed the sum of (i) the rate base established by the Commission in the electric utility's last rate case prior to the effective date of this amendatory Act of 1997, plus (ii) any expenditures required to be undertaken by such electric utility by the provisions of Section 16-128 of this Act, including labor severance costs and employee retraining costs, plus (iii) amounts necessary to fund debt service and other reserves, commercially reasonable costs and fees necessary in connection with the marketing of the transitional funding instruments and grantee instruments, if any, plus (iv) commercially reasonable costs incurred from and after the effective date of this amendatory Act of 1997 or to be incurred which are associated with the issuance and collateralization of transitional funding instruments and grantee instruments, if any, plus (v) commercially reasonable costs incurred from and after the effective date of this amendatory Act of 1997 or to be incurred which are associated with issuance of such transitional funding instruments, including the costs incurred from and after the effective date of this amendatory Act of 1997, or to be incurred, in connection with transactions to recapitalize, refinance or retire stock and/or debt, any associated taxes and the costs incurred to obtain, collateralize, issue, service and/or administer transitional funding instruments and grantee instruments, if any, including interest and other related fees, costs and charges (all of the foregoing costs described in clauses (i) through (v) above to include any taxes, where applicable, to the extent the costs thereof would otherwise have been recoverable by an electric utility through rates for tariffed services under the Public Utilities Act as in effect prior to this amendatory Act of 1997), minus (vi) the amount of any intangible transition property previously created and established at the request of and for the benefit of such electric utility in a prior transitional funding order. The transitional funding order shall authorize (A) the sale, pledge, assignment or other transfer of, or the establishment, creation and granting of an electric utility's, assignee's or grantee's rights in and to, a specific dollar amount of intangible transition property (which amount may be in excess of the principal and interest payable on the transitional funding instruments and grantee instruments, if any, in order to provide for servicing costs and the funding or maintenance of debt service and other reserves as security to the holders of the transitional funding instruments), (B) the issuance of a specific dollar amount of grantee instruments or, if the transitional funding order does not provide for the issuance of grantee instruments, a specific dollar amount of transitional funding instruments, by or on behalf of an electric utility, assignee, issuer or grantee, as the case may be, and (C) the imposition and collection of a specific amount of instrument funding charges projected to be sufficient to pay when due the principal of and interest on the corresponding grantee instruments or, if the transitional funding order does not provide for the issuance of grantee instruments, the corresponding transitional funding instruments, in each case, together with premium, servicing fees and other fees, costs and charges related thereto, and to maintain any required reserves. Except as otherwise specifically set forth in the transitional funding order, the transitional funding instruments issued pursuant to such order shall be non-recourse to the credit or to any assets of the electric utility other than any assets comprising intangible transition property or grantee instruments, as applicable. The obligation of retail customers and other persons to pay instrument funding charges shall be contingent upon the receipt by such retail customers and other persons of electric power and energy, the kilowatt hours of which are included in the calculation of the dollar amount of such instrument funding charges, but the transitional funding order shall specifically provide that such instrument funding charges will not be subject to any defense, counterclaim or right of set off arising as a result of failure by the pertinent electric utility, upon whose application the intangible transition property was created, to perform or provide past, present or future services. For purposes of the foregoing sentence, an electric utility or alternative retail electric supplier obligated to pay transition charges under subsection (b) of Section 16-118 on behalf of certain retail customers shall be deemed to have received the electric power and energy provided to such retail customers. The transitional funding order shall also set forth the time to maturity for the grantee instruments or, if the transitional funding order does not provide for the issuance of grantee instruments, the time to maturity for the transitional funding instruments issued thereunder. Concurrently with the sale, pledge, assignment or other transfer of, or the establishment, creation and granting of an electric utility's, assignee's or grantee's rights in and to, intangible transition property and grantee instruments, if any, and the issuance of transitional funding instruments, an electric utility, grantee, issuer or an assignee shall begin to impose and collect the specified instrument funding charges from retail customers, classes of retail customers, and any other persons or groups of persons as set forth in the pertinent transitional funding order and shall file tariffs in accordance with subsection (j) of Section 18-104 of this Article.

(b) The transitional funding order shall require that the proceeds from the issuance of transitional funding instruments shall be used for the purposes set forth in subparagraph (1) of subsection (d) of Section 18-103 of this Article.

(c) Notwithstanding any other provision of law, neither the transitional funding order nor the intangible transition property created and established thereby nor the instrument funding charges authorized to be imposed and collected thereunder shall be subject to reduction, postponement, impairment or termination by any subsequent action of the Commission; provided, however, that nothing in this paragraph is intended to supersede any right of any party to the Commission's proceeding relating to the transitional funding order to seek judicial review of such transitional funding order.

(d) The Commission shall provide in any transitional funding order for a procedure for periodic adjustments to the instrument funding charges set forth therein in order to ensure the repayment in accordance with the projections set forth in the transitional funding order of all grantee instruments or, if such transitional funding order does not provide for the issuance of grantee instruments, the corresponding transitional funding instruments authorized therein and to reconcile the revenues received from instrument funding charges during the applicable adjustment period with the revenues projected to be received from such charges as set forth in the relevant transitional funding order. Unless the transitional funding order otherwise provides, such adjustments shall be required whenever the instrument funding charges actually collected during the applicable adjustment period by the appropriate party or parties were greater or less than the instrument funding charges projected in the relevant transitional funding order to be collected in such adjustment period; provided that, if so requested by an electric utility in any application for a transitional funding order, the transitional funding order may (i) specify a dollar or percentage amount of variation from the projected revenues within which no such adjustments will be required and/or (ii) set forth a maximum adjustment amount for the instrument funding charges. The electric utility (or such other party as may be specified in the pertinent transitional funding order) shall determine, within 90 days of the end of each adjustment period (or such shorter period as may be provided in the documents relating to the pertinent transitional funding instruments or grantee instruments, as applicable), whether any adjustments described above in this subsection (d) of Section 18-104 are required. If any such adjustments are so required, such adjustments shall be implemented by the electric utility, grantee, issuer or assignee, as applicable, with written notice to the Commission, within such 90-day period (or such shorter period as may be provided for in the documents relating to the pertinent transitional funding instruments or grantee instruments, as applicable). Any such adjustment shall be calculated to include amounts necessary for recovery of any additional costs incurred by the grantee, electric utility, assignee or issuer as a result of the relevant delay in collections of instrument funding charges. If, as a result of any adjustment, the amount of any instrument funding charge, as so adjusted, will exceed an amount per kilowatt-hour greater than the amount per kilowatt-hour of the instrument funding charge initially authorized by the Commission in its transitional funding order, then the relevant electric utility shall be obligated to file amendatory tariffs in compliance with subsection (k) of Section 18-104.

(e) Except where this Article specifically requires otherwise, the collection of instrument funding charges and the allocation of any such collections as among holders, assignees, issuers, grantees and any other parties entitled to receive portions thereof, may be accomplished according to the provisions set forth in the applicable transitional funding order, or, if the order is silent on any such matters, according to the provisions set forth in the documents relating to the pertinent transitional funding instruments or grantee instruments, as applicable. Notwithstanding the foregoing, the electric utility, grantee, issuer or assignee, as applicable, shall determine no later than 90 days after the stated maturity date of each series of grantee instruments or, if the related transitional funding order does not provide for the issuance of grantee instruments, the stated maturity date of transitional funding instruments, whether the aggregate amount of instrument funding charges collected prior to such stated maturity date exceeds the amount required to provide for the payment of all principal, interest, premium and servicing and other fees, costs and charges owing under such grantee instruments or transitional funding instruments, as the case may be. If it is determined that the aggregate amount of instrument funding charges collected exceeds the amount required to provide for the payment of all principal, interest, premium and servicing and other fees, costs and charges related to such grantee instruments or transitional funding instruments, as the case may be, such excess, together with any investment earnings thereon, shall be paid to the owner of the pertinent intangible transition property.

(f) Notwithstanding any other provision of law, on such conditions as the Commission may approve in the pertinent transitional funding order, the interest of an electric utility, assignee, issuer or grantee in intangible transition property or grantee instruments, as applicable, may be assigned, sold or otherwise transferred, in whole or in part, and may, in whole or in part, be pledged or assigned as security to or for the benefit of a holder or holders. To the extent that any such interest or portion thereof is assigned, sold or otherwise transferred or is established, created and granted to a grantee or is pledged or assigned as security, the Commission, in the pertinent transitional funding order, shall authorize the electric utility or any affiliate thereof to contract with the grantee, issuer, assignee or holders to collect the applicable instrument funding charges for the benefit and account of the grantee, issuer, assignee or holder, and such electric utility or affiliate will, except as otherwise specified in the transitional funding order, account for and remit the applicable instrument funding charge, without the obligation to remit any investment earnings thereon, to or for the account of the grantee, issuer, assignee or holder. The obligation of such electric utility or affiliate to collect and remit the applicable instrument funding charges hereunder shall continue irrespective of whether such electric utility is providing electric power and/or other services to the retail customers and other persons obligated to pay such instrument funding charges. If the documents creating the transitional funding instruments or grantee instruments, if any, so provide, such obligations shall, in the event of a default by such electric utility or affiliate in performing such obligations, be undertaken and performed by any other entity selected by the assignee or any holder, group of holders or trustee or agent on behalf of such holder or holders, as the case may be, (i) which provides electric power or services to a person that was a retail customer of such electric utility and (ii) from whom such electric utility is entitled to recover transition charges under Section 16-108; provided, however, that any failure by the designated party to perform such obligations shall not affect the existence of the intangible transition property or the instrument funding charges or the validity or enforceability of the instrument funding charges in accordance with their terms.

(g) In its transitional funding order, the Commission shall afford flexibility in establishing the terms and conditions of the transitional funding instruments and the grantee instruments, if any, including repayment schedules, collateral, required debt service and other reserves, interest rates and other financing costs and the ability of the electric utility, at its option, to effect a series of issuances of transitional funding instruments and grantee instruments and correlated assignments, sales, pledges or other transfers of intangible transition property and grantee instruments, if any, not to exceed the aggregate dollar amounts approved in the transitional funding order.

(h) The electric utility shall file a statement of the final terms of the issuance of any series of transitional funding instruments or grantee instruments, if any, with the Commission within 90 days of the receipt of proceeds from such issuance. In addition, the Commission may require the electric utility to file periodic reports on its use of the proceeds at intervals of not less than one year.

(i) Any adjustment to instrument funding charges that is necessary due to subsequent refinancing of transitional funding instruments or grantee instruments, if any, shall be authorized by the Commission in a supplemental order.

(j) In connection with the issuance of a transitional funding order and as a precondition to the imposition of any instrument funding charges authorized thereby, the relevant electric utility shall file tariffs directing that the amount of such instrument funding charges be deducted, stated, and collected separately from the amounts otherwise billed by such electric utility for base rates and transition charges and, where applicable, other rates for tariffed services as set forth in the transitional funding order. Upon the effectiveness of such tariff, the amounts of instrument funding charges thereby deducted and to be deducted shall have become intangible transition property as specified in the transitional funding order. The Commission shall have no authority to review such tariffs except to confirm that the instrument funding charges authorized in the transitional funding order have been deducted, stated, and collected separately from base rates and transition charges and, where applicable, other rates for tariffed services otherwise in effect at such time, and the filing of any such tariff may not be suspended for any other reason. No such deductions referred to in this subsection shall be construed as a change in or otherwise require a recalculation of the authorized amounts of such base rates, transition charges, and other rates for tariffed services under Section 16-102, 16-107, 16-108, or 16-110, as applicable. Instrument funding charges shall be recoverable with respect to electric power and energy or other services for which the deductions provided in this subsection have become effective and no such deduction shall be effective with respect to any services or power in respect of which instrument funding charges have not been so authorized and imposed.

(k) If any adjustment under subsection (d) of Section 18-104 results in the amount of any instrument funding charge as so adjusted exceeding an amount per kilowatt-hour greater than the amount per kilowatt-hour of the instrument funding charge initially authorized by the Commission in its transitional funding order, the relevant electric utility shall file amendatory tariffs reducing the amounts otherwise billed by such electric utility for base rates and transition charges or, where applicable, other rates for tariffed services, by the amount of such excess. Such amendatory tariff shall be subject to the provisions of subsection (j) of Section 18-104, except that (i) the failure of such amendatory tariff to become effective for any reason shall not delay or impair the effectiveness of the adjustments required under subsection (d) of Section 18-104 and (ii) the obligation of retail customers and other persons or groups of persons to pay instrument funding charges as so adjusted shall not be subject to any defense, counterclaim or right of set off arising as a result of failure by the pertinent electric utility to comply with this subsection (k) of Section 18-104. Nothing in this subsection (k) of Section 18-104 shall restrict any retail customer or other person from bringing any suit in any court or from exercising any other legal or equitable remedy against an electric utility for any failure by such electric utility to comply with this subsection (k) of Section 18-104.

(l) The intangible transition property created under a transitional funding order and the authority of the grantee, assignee, issuer, electric utility or other person authorized thereunder to impose and collect instrument funding charges shall continue beyond the final date set forth in the applicable transitional funding order until such time as all grantee instruments authorized in such order or, if the applicable transitional funding order does not provide for grantee instruments, the related transitional funding instruments authorized in such order, have been paid in full.

Upon the later of the final date set forth in the applicable transitional funding order for the imposition and collection of instrument funding charges or the repayment in full of any grantee instruments or transitional funding instruments, as applicable, authorized in such order, the authority to impose and collect the related instrument funding charges shall cease and the relevant electric utility shall be entitled to file tariffs revoking any deductions from base rates, transition charges or other rates for tariffed services which were granted in connection with such instrument funding charges pursuant to subsection (j) of Section 18-104 or subsection (k) of Section 18-104. The Commission shall have no authority to review such tariffs except to determine that the rates and charges resulting from such revocation do not exceed the applicable base rates, transition charges, or other rates for tariffed services which would otherwise have been in effect at the time of such revocation had no instrument funding charges ever been deducted therefrom.

(m) If so requested by an electric utility in its application for a transitional funding order, the Commission, in the relevant transitional funding order, may authorize (i) the issuance of grantee instruments and/or transitional funding instruments with expected maturity dates later than December 31, 2008 but not later than December 31, 2010 and (ii) the imposition and collection of instrument funding charges by electric utilities, grantees, or assignees later than December 31, 2008 but not later than December 31, 2010 if the electric utility includes in its application a pro forma calculation of the impact of the issuance of the transitional funding instruments or grantee instruments and the associated use of proceeds on the revenue requirement established by the Commission in the electric utility's last rate case, with such calculation to be presented for illustrative purposes only, and the Commission, in its review of the relevant application for the transitional funding order, finds that such action is in the public interest and that the instrument funding charges to be applied toward payment of transitional funding instruments after December 31, 2008 will be deducted, stated, and collected separately from base rates and, where applicable, other rates for tariffed services otherwise in effect at such time and as scheduled to be in effect through such expected maturity date.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/18-105)

Sec. 18-105. Intangible transition property.

(a) Notwithstanding any other provision of this Act or other law, the Commission is hereby authorized, in accordance with the application for a transitional funding order, to create, establish and grant rights in, to and under intangible transition property in and to any grantee, electric utility, issuer or assignee, and such party shall be granted the power to levy general tariffs on retail customers of an electric utility or any other person required to pay an instrument funding charge in order to collect the instrument funding charges related to the intangible transition property in which such party has been granted rights and in order to facilitate the issuance of transitional funding instruments and grantee instruments, if any, to, by or on behalf of electric utilities, grantees, issuers or assignees. The Commission shall be authorized to create, establish and grant such rights hereunder in and to such party with or without receiving consideration from such party.

(b) The State pledges to and agrees with the holders of any transitional funding instruments who may enter into contracts with an electric utility, grantee, assignee or issuer pursuant to this Article XVIII that the State will not in any way limit, alter, impair or reduce the value of intangible transition property created by, or instrument funding charges approved by, a transitional funding order so as to impair the terms of any contract made by such electric utility, grantee, assignee or issuer with such holders or in any way impair the rights and remedies of such holders until the pertinent grantee instruments or, if the related transitional funding order does not provide for the issuance of grantee instruments, the pertinent transitional funding instruments and interest, premium and other fees, costs and charges related thereto, as the case may be, are fully paid and discharged. Electric utilities, grantees and issuers are authorized to include these pledges and agreements of the State in any contract with the holders of transitional funding instruments or with any assignees pursuant to this Article XVIII and any assignees are similarly authorized to include these pledges and agreements of the State in any contract with any issuer, holder or any other assignee. Nothing in this Article XVIII shall preclude the State of Illinois from requiring adjustments as may otherwise be allowed by law to the electric utility's base rates, transition charges, delivery services charges, or other charges for tariffed services, so long as any such adjustment does not directly affect or impair any instrument funding charges previously authorized by a transitional funding order issued by the Commission.

(c) Transitional funding instruments and grantee instruments, if any, issued under this Article do not constitute debt or liability of the State or of any political subdivision thereof, and transitional funding orders authorizing such issuance do not constitute a pledge of the full faith and credit of the State or of any of its political subdivisions. The issuance of transitional funding instruments and grantee instruments, if any, under this Article shall not directly, indirectly or contingently obligate the State or any political subdivision thereof to levy or to pledge any form of taxation therefor or to make any appropriation for their payment, and any such transitional funding instruments and grantee instruments, if any, shall be payable solely from the intangible transition property or grantee instruments, as the case may be, or from such other proceeds or property as may be pledged therefor. Nothing in this Section shall be construed to prevent the State or any political subdivision thereof from owning any interest in a grantee, assignee or issuer or to prevent any electric utility, issuer, grantee or assignee from selling, pledging or assigning intangible transition property or grantee instruments, as the case may be, or from providing recourse or guarantees or any other third-party credit enhancement in connection with such sale, pledge or assignment.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/18-106)

Sec. 18-106. Grantee instruments.

(a) If an electric utility to which grantee instruments have been issued discontinues providing electric power and energy services prior to the maturity date of such grantee instruments, such electric utility shall not be entitled to receive any payment on such grantee instruments on and after the date of such discontinuance.

(b) Notwithstanding the provisions of subsection (a) of this Section, any assignee holding such grantee instruments or any holder of transitional funding instruments which are secured by such grantee instruments shall nevertheless be entitled to recover amounts payable by such grantee under such grantee instruments in accordance with their terms as if such electric utility had not discontinued the provision of electric power and energy.

(c) Notwithstanding any other provision of law, the issuance of any grantee instruments in accordance with the terms and provisions of a transitional funding order shall for all purposes be exempt from the application of Section 17-59 or Article 39 of the Criminal Code of 2012 or the Criminal Code of 1961 and the Interest Act.

(Source: P.A. 97-1150, eff. 1-25-13.)

(220 ILCS 5/18-107)

Sec. 18-107. Security interests in intangible transition property and grantee instruments.

(a) Notwithstanding any other provision of law, neither intangible transition property, grantee instruments nor any right, title or interest therein, shall constitute property in which a security interest may be created under the Uniform Commercial Code nor shall any such rights be deemed proceeds of any property which is not intangible transition property or grantee instruments, as the case may be. For purposes of the foregoing, the terms "account", "general intangible", "instrument", and "payment intangible" (as defined under Section 9-102 of the Uniform Commercial Code) shall, as used in the Uniform Commercial Code, be deemed to exclude any such intangible transition property, grantee instruments or any right, title, or interest therein.

(b) The granting, perfection and enforcement of security interests in intangible transition property or grantee instruments are governed by this Section rather than by Article 9 of the Uniform Commercial Code.

(c) A valid and enforceable security interest in intangible transition property and in grantee instruments shall attach and be perfected only by the means set forth below in this subsection (c) of Section 18-107:

(1) To the extent transitional funding instruments or grantee instruments are purported to be secured by intangible transition property or to the extent transitional funding instruments are purported to be secured by grantee instruments, as the case may be, as specified in the applicable transitional funding order, the lien of the transitional funding instruments and grantee instruments, if any, shall attach automatically to such intangible transition property and grantee instruments, if any, from the time of issuance of the transitional funding instruments and grantee instruments, if any. Such lien shall be a valid and enforceable security interest in the intangible transition property or the grantee instruments, as the case may be, securing the transitional funding instruments and grantee instruments, if any, and shall be continuously perfected if, before the date of issuance of the applicable transitional funding instruments or grantee instruments, if any, or within no more than 10 days thereafter, a filing has been made by or on behalf of the holder with the Chief Clerk of the Commission stating that such transitional funding instruments or grantee instruments, if any, have been issued. Any such filing made with the Commission in respect to such transitional funding instruments or grantee instruments shall take precedence over any subsequent filing except as may otherwise be provided in the applicable transitional funding order.

(2) The liens under subparagraph (1) are enforceable against the electric utility, any assignee, grantee or issuer, and all third parties, including judicial lien creditors, subject only to the rights of any third parties holding security interests in the intangible transition property or grantee instruments previously perfected in the manner described in this subsection if value has been given by the purchasers of transitional funding instruments or grantee instruments. A perfected lien in intangible transition property and grantee instruments, if any, is a continuously perfected security interest in all then existing or thereafter arising revenues and proceeds arising with respect to the associated intangible transition property or grantee instruments, as the case may be, whether or not the electric power and energy included in the calculation of such revenues and proceeds have been provided. The lien created under this subsection is perfected and ranks prior to any other lien, including any judicial lien, which subsequently attaches to the intangible transition property or grantee instruments, as the case may be, and to any other rights created by the transitional funding order or any revenues or proceeds of the foregoing. The relative priority of a lien created under this subsection is not defeated or adversely affected by changes to the transitional funding order or to the instrument funding charges payable by any retail customer, class of retail customers or other person or group of persons obligated to pay such charges.

(3) The relative priority of a lien created under this subsection is not defeated or adversely affected by the commingling of revenues arising with respect to intangible transition property or grantee instruments with funds of the electric utility or other funds of the assignee, issuer or grantee.

(4) If an event of default occurs under transitional funding instruments or grantee instruments, the holders thereof or their authorized representatives, as secured parties, may foreclose or otherwise enforce the lien in the grantee instruments or in the intangible transition property securing the transitional funding instruments or grantee instruments, as applicable, subject to the rights of any third parties holding prior security interests in the intangible transition property or grantee instruments previously perfected in the manner provided in this subsection. Upon application by the holders or their authorized representatives, without limiting their other remedies, the Commission shall order the sequestration and payment to the holders or their authorized representatives of revenues arising with respect to the intangible transition property or grantee instruments pledged to the holders. An order under this subsection shall remain in full force and effect notwithstanding any bankruptcy, reorganization, or other insolvency proceedings with respect to the electric utility, grantee, assignee or issuer.

(5) The Commission shall maintain segregated records which reflect the date and time of receipt of all filings made under this subsection. The Commission may provide that transfers of intangible transition property or of grantee instruments be filed in accordance with the same system.

(Source: P.A. 90-561, eff. 12-16-97; 91-893, eff. 7-1-01.)

(220 ILCS 5/18-108)

Sec. 18-108. Characterization of transfer. A sale, assignment or other transfer of intangible transition property or grantee instruments which is expressly stated in the documents governing such transaction to be a sale or other absolute transfer, in a transaction approved in a transitional funding order, shall be treated as an absolute transfer of all of the transferor's right, title and interest in, to and under such intangible transition property or grantee instruments which places such transferred property beyond the reach of the transferor or its creditors, as in a true sale, and not as a pledge or other financing, of such intangible transition property or grantee instruments, as the case may be; provided, however, that whether or not such transfer is deemed to be a sale for federal tax purposes shall be governed by applicable law without regard to this Section 18-108. The characterization of any such transfer as an absolute transfer and the corresponding characterization of the transferee's property interest shall not be defeated or adversely affected by, among other things: (i) the commingling of revenues arising with respect to intangible transition property or grantee instruments, as the case may be, with funds of the electric utility or other funds of the assignee, issuer or grantee; (ii) granting to holders of transitional funding instruments a preferred right to the intangible transition property, whether direct or indirect; (iii) the provision by the electric utility, grantee, assignee, or issuer of any recourse, collateral or credit enhancement with respect to transitional funding instruments or grantee instruments, as the case may be; (iv) the retention by the assigning party of a partial interest in any intangible transition property, whether direct or indirect, or whether subordinate or otherwise; or (v) the electric utility's responsibilities for collecting instrument funding charges and any retention of bare legal title for the purpose of such collection activities; provided, however, that nothing in this Section 18-108 is intended to preclude consideration of such provisions in determining whether or not such transfer is deemed to be a sale for federal tax purposes under other applicable law. A sale, assignment, or other transfer of intangible transition property or grantee instruments, as the case may be, shall be deemed perfected as against third persons, including any judicial lien creditors, when all of the following have taken place:

(1) The Commission has issued the transitional funding order creating the intangible transition property; and

(2) A sale, assignment or transfer of the intangible transition property or grantee instruments, as the case may be, has been executed and delivered in writing by the electric utility.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/18-109)

Sec. 18-109. Actions with respect to intangible transition property and related instrument funding charges.

(a) Notwithstanding any other provision of this Act or other law, any electric utility, issuer, assignee, grantee or holder shall be expressly permitted hereby to bring action against a retail customer or other person for nonpayment of any instrument funding charges constituting a part of the intangible transition property then held by such electric utility, issuer, assignee, grantee or holder. Notwithstanding any other provision of this Act, any such action shall be subject to any and all applicable consumer credit protection laws and other laws relating to origination, collection and reporting of consumer credit obligations.

(b) Notwithstanding any other provision of this Act or other law, the Commission shall have exclusive jurisdiction over any dispute arising out of the obligations to impose and collect instrument funding charges of an electric utility, its successor or any other entity which provides electric power or energy or delivery services to a person from whom the electric utility is authorized to recover transition charges under Section 16-108. Nothing in this Section shall prevent holders from bringing any suit in any court or from exercising any other legal or equitable remedy against an electric utility for failure to distribute collections of instrument funding charges from retail customers, classes of retail customers or other persons or from bringing suit against an electric utility for damages arising from any failure by such electric utility to perform the contractual obligations agreed to by it under any documents pertaining to or executed in connection with the transitional funding instruments issued by or on behalf of such electric utility.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/18-110)

Sec. 18-110. Taxation of transfers of intangible transition property and grantee instruments.

(a) Any sale, pledge, assignment or other transfer of intangible transition property and grantee instruments, if any, shall be exempt from any State or local sales, income, transfers, gains, receipts or similar taxes.

(b) Any transfer of intangible transition property and grantee instruments, if any, shall be treated as a pledge or other financing for State tax purposes, including State and local income and franchise taxes, unless the documents governing such transfer specifically state that the transfer is intended to be treated otherwise.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/18-111)

Sec. 18-111. Limitations on issuance of transitional funding orders, collection of instrument funding charges, and use of proceeds from issuance of transitional funding instruments and grantee instruments.

Notwithstanding any other provisions of this Article XVIII:

(1) The Commission shall be prohibited from issuing any transitional funding order prior to January 1, 1998, and no electric utility shall issue any transitional funding instrument or grantee instrument, prior to August 1, 1998, or after December 31, 2004.

(2) The Commission shall be authorized to include in any transitional funding order an expiration date after which date the electric utility shall no longer be authorized to issue transitional funding instruments or grantee instruments pursuant to such order, provided, that any such expiration date specified in a transitional funding order shall be no earlier than 24 months following the date of issuance of the relevant transitional funding order.

(3) No electric utility shall be allowed to increase its rates for tariffed services, including delivery charges, or its transition charges, above the level or levels which would have been allowed in accordance with this Act if the electric utility were not authorized to impose and collect instrument funding charges.

(4) Any transitional funding order issued by the Commission shall set forth, based on the information set forth in the electric utility's application, the procedures to be followed by the electric utility for assuring that proceeds from the issuance of the transitional funding instruments or grantee instruments authorized by such order are applied in accordance with the terms of the order. Any use by an electric utility of the proceeds from issuance of transitional funding instruments or grantee instruments other than in accordance with the purposes specified in the relevant transitional funding order of the Commission, pursuant to subsection (d) of Section 18-103, shall be void.

(Source: P.A. 90-561, eff. 12-16-97.)

(220 ILCS 5/Art. XIX heading) ARTICLE XIX. ALTERNATIVE GAS SUPPLIER LAW

(220 ILCS 5/19-100)

Sec. 19-100. Short title. This Article may be cited as the Alternative Gas Supplier Law.

(Source: P.A. 92-529, eff. 2-8-02.)

(220 ILCS 5/19-105)

Sec. 19-105. Definitions. For the purposes of this Article, the following terms shall be defined as set forth in this Section.

"Alternative gas supplier" means every person, cooperative, corporation, municipal corporation, company, association, joint stock company or association, firm, partnership, individual, or other entity, their lessees, trustees, or receivers appointed by any court whatsoever, that offers gas for sale, lease, or in exchange for other value received to one or more customers, or that engages in the furnishing of gas to one or more customers, and shall include affiliated interests of a gas utility, resellers, aggregators and marketers, but shall not include (i) gas utilities (or any agent of the gas utility to the extent the gas utility provides tariffed services to customers through an agent); (ii) public utilities that are owned and operated by any political subdivision, public institution of higher education or municipal corporation of this State, or public utilities that are owned by a political subdivision, public institution of higher education, or municipal corporation and operated by any of its lessees or operating agents; (iii) natural gas cooperatives that are not-for-profit corporations operated for the purpose of administering, on a cooperative basis, the furnishing of natural gas for the benefit of their members who are consumers of natural gas; and (iv) the ownership or operation of a facility that sells compressed natural gas at retail to the public for use only as a motor vehicle fuel and the selling of compressed natural gas at retail to the public for use only as a motor vehicle fuel.

"Gas utility" means a public utility, as defined in Section 3-105 of this Act, that has a franchise, license, permit, or right to furnish or sell gas or transportation services to customers within a service area.

"Residential customer" means a customer who receives gas utility service for household purposes distributed to a dwelling of 2 or fewer units which is billed under a residential rate or gas utility service for household purposes distributed to a dwelling unit or units which is billed under a residential rate and is registered by a separate meter for each dwelling unit.

"Sales agent" means any employee, agent, independent contractor, consultant, or other person that is engaged by the alternative gas supplier to solicit customers to purchase, enroll in, or contract for alternative gas service on behalf of an alternative gas supplier.

"Service area" means (i) the geographic area within which a gas utility was lawfully entitled to provide gas to customers as of the effective date of this amendatory Act of the 92nd General Assembly and includes (ii) the location of any customer to which the gas utility was lawfully providing gas utility services on such effective date.

"Single billing" means the combined billing of the services provided by both a natural gas utility and an alternative gas supplier to any customer who has enrolled in a customer choice program.

"Small commercial customer" means a nonresidential retail customer of a natural gas utility who consumed 5,000 or fewer therms of natural gas during the previous year; provided that any alternative gas supplier may remove the customer from designation as a "small commercial customer" if the customer consumes more than 5,000 therms of natural gas in any calendar year after becoming a customer of the alternative gas supplier. In determining whether a customer has consumed 5,000 or fewer therms of natural gas during the previous year, usage by the same commercial customer shall be aggregated to include usage at the same premises even if measured by more than one meter, and to include usage at multiple premises. Nothing in this Section creates an affirmative obligation on a gas utility to monitor or inform customers or alternative gas suppliers as to a customer's status as a small commercial customer as that term is defined herein. Nothing in this Section relieves a gas utility from any obligation to provide information upon request to a customer, alternative gas supplier, the Commission, or others necessary to determine whether a customer meets the classification of small commercial customers as that term is defined herein.

"Tariffed service" means a service provided to customers by a gas utility as defined by its rates on file with the Commission pursuant to the provisions of Article IX of this Act.

"Transportation services" means those services provided by the gas utility that are necessary in order for the storage, transmission and distribution systems to function so that customers located in the gas utility's service area can receive gas from suppliers other than the gas utility and shall include, without limitation, standard metering and billing services.

(Source: P.A. 95-1051, eff. 4-10-09; 96-435, eff. 1-1-10; 96-1000, eff. 7-2-10.)

(220 ILCS 5/19-110)

Sec. 19-110. Certification of alternative gas suppliers.

(a) The provisions of this Section shall apply only to alternative gas suppliers serving or seeking to serve residential or small commercial customers and only to the extent such alternative gas suppliers provide services to residential or small commercial customers.

(b) An alternative gas supplier must obtain a certificate of service authority from the Commission in accordance with this Section before serving any customer or other user located in this State. An alternative gas supplier may request, and the Commission may grant, a certificate of service authority for the entire State or for a specified geographic area of the State. A certificate granted pursuant to this Section is not property, and the grant of a certificate to an entity does not create a property interest in the certificate. This Section does not diminish the existing rights of a certificate holder to notice and hearing as proscribed by the Illinois Administrative Procedure Act and in rules adopted by the Commission. A person, corporation, or other entity acting as an alternative gas supplier on the effective date of this amendatory Act of the 92nd General Assembly shall have 180 days from the effective date of this amendatory Act of the 92nd General Assembly to comply with the requirements of this Section in order to continue to operate as an alternative gas supplier.

(c) An alternative gas supplier seeking a certificate of service authority shall file with the Commission a verified application containing information showing that the applicant meets the requirements of this Section. The alternative gas supplier shall publish notice of its application in the official State newspaper within 10 days following the date of its filing. No later than 45 days after a complete application is properly filed with the Commission, and such notice is published, the Commission shall issue its order granting or denying the application.

(d) An application for a certificate of service authority shall identify the area or areas in which the applicant intends to offer service and the types of services it intends to offer. Applicants that seek to serve residential or small commercial customers within a geographic area that is smaller than a gas utility's service area shall submit evidence demonstrating that the designation of this smaller area does not violate Section 19-115. An applicant may state in its application for certification any limitations that will be imposed on the number of customers or maximum load to be served. The applicant shall submit as part of its application a statement indicating:

(1) Whether the applicant has been denied a natural gas supplier license in any state in the United States.

(2) Whether the applicant has had a natural gas supplier license suspended or revoked by any state in the United States.

(3) Where, if any, other natural gas supplier license applications are pending in the United States.

(4) Whether the applicant is the subject of any lawsuits filed in a court of law or formal complaints filed with a regulatory agency alleging fraud, deception, or unfair marketing practices, or other similar allegations, identifying the name, case number, and jurisdiction of each such lawsuit or complaint.

For the purposes of this subsection (d), formal complaints include only those complaints that seek a binding determination from a state or federal regulatory body.

(e) The Commission shall grant the application for a certificate of service authority if it makes the findings set forth in this subsection based on the verified application and such other information as the applicant may submit.

(1) That the applicant possesses sufficient technical, financial, and managerial resources and abilities to provide the service for which it seeks a certificate of service authority. In determining the level of technical, financial, and managerial resources and abilities which the applicant must demonstrate, the Commission shall consider:

(A) the characteristics, including the size and financial sophistication of the customers that the applicant seeks to serve;

(B) whether the applicant seeks to provide gas using property, plant, and equipment that it owns, controls, or operates; and

(C) the applicant's commitment of resources to the management of sales and marketing staff, through affirmative managerial policies, independent audits, technology, hands-on field monitoring and training, and, in the case of applicants who will have sales personnel or sales agents within the State of Illinois, the applicant's managerial presence within the State.

(2) That the applicant will comply with all applicable federal, State, regional, and industry rules, policies, practices, and procedures for the use, operation, and maintenance of the safety, integrity, and reliability of the gas transmission system.

(3) That the applicant will comply with such informational or reporting requirements as the Commission may by rule establish.

(4) That the area to be served by the applicant and any limitations it proposes on the number of customers or maximum amount of load to be served meet the provisions of Section 19-115, provided, that if the applicant seeks to serve an area smaller than the service area of a gas utility or proposes other limitations on the number of customers or maximum amount of load to be served, the Commission can extend the time for considering such a certificate request by up to 90 days, and can schedule hearings on such a request.

(5) That the applicant shall continue to comply with requirements for certification stated in this Section.

(6) That the applicant shall execute and maintain a license or permit bond issued by a qualifying surety or insurance company authorized to transact business in the State of Illinois in favor of the People of the State of Illinois. The amount of the bond shall equal $150,000 if the applicant seeks to serve only nonresidential retail customers or $500,000 if the applicant seeks to serve all eligible customers. Applicants shall be required to submit an additional $500,000 bond if the applicant intends to market to residential customers using in-person solicitations. The bonds shall be conditioned upon the full and faithful performance of all duties and obligations of the applicant as an alternative retail gas supplier, shall be valid for a period of not less than one year, and may be drawn up to satisfy any penalties imposed and finally adjudicated, by the Commission pursuant to Section 19-120 for a violation of the applicant's duties or obligations, except that the total amount of claims and penalties against the bond shall not exceed the penal sum of the bond and shall not include any consequential or punitive damage. The cost of the bond shall be paid by the applicant. The applicant shall file a copy of this bond, with a notarized verification page from the issuer, as part of its application for certification under 83 Ill. Adm. Code 551.

(7) That the applicant will comply with all other applicable laws and rules.

(e-5) The Commission may deny with prejudice an application in which the applicant fails to provide the Commission with information sufficient for the Commission to grant the application.

(f) The Commission can extend the time for considering such a certificate request by up to 90 days, and can schedule hearings on such a request if:

(1) a party to the application proceeding has formally requested that the Commission hold hearings in a pleading that alleges that one or more of the allegations or certifications in the application is false or misleading; or

(2) other facts or circumstances exist that will necessitate additional time or evidence in order to determine whether a certificate should be issued.

(g) The Commission shall have the authority to promulgate rules to carry out the provisions of this Section. Within 30 days after the effective date of this amendatory Act of the 92nd General Assembly, the Commission shall adopt an emergency rule or rules applicable to the certification of those gas suppliers that seek to serve residential customers. Within 180 days of the effective date of this amendatory Act of the 92nd General Assembly, the Commission shall adopt rules that specify criteria which, if met by any such alternative gas supplier, shall constitute the demonstration of technical, financial, and managerial resources and abilities to provide service required by paragraph (1) of subsection (e) of this Section, such as a requirement to post a bond or letter of credit, from a responsible surety or financial institution, of sufficient size for the nature and scope of the services to be provided, demonstration of adequate insurance for the scope and nature of the services to be provided, and experience in providing similar services in other jurisdictions.

(h) The Commission may deny with prejudice any application that repeatedly fails to include the attachments, documentation, and affidavits required by the application form or that fails to provide any other information required by this Section.

(i) An alternative gas supplier may seek confidential treatment for the reporting to the Commission of its total annual dekatherms delivered and sold by it to residential and small commercial customers by utility service territory during the preceding year via the filing of an affidavit with the Commission so long as the affidavit meets the requirements of this subsection (i). The affidavit must be filed contemporaneously with the information for which confidential treatment is sought and must clearly state that the affiant seeks confidential treatment pursuant to this subsection (i) and the information for which confidential treatment is sought must be clearly identified on the confidential version of the document filed with the Commission. The affidavit must be accompanied by both a "confidential" and a "public" version of the document or documents containing the information for which confidential treatment is sought.

If the alternative gas supplier has met the affidavit requirements of this subsection (i), then the Commission shall afford confidential treatment to the information identified in the affidavit for a period of 2 years after the date the affidavit is received by the Commission.

Nothing in this subsection (i) prevents an alternative gas supplier from filing a petition with the Commission seeking confidential treatment for information beyond that identified in this subsection (i) or for information contained in other reports or documents filed with the Commission other than annual rate reports.

Nothing in this subsection (i) prevents the Commission, on its own motion, or any party from filing a formal petition with the Commission seeking to reconsider the conferring of confidential status pursuant to this subsection (i).

The Commission, on its own motion, may at any time initiate a docketed proceeding to investigate the continued applicability of this affidavit-based process for seeking confidential treatment. If, at the end of such investigation, the Commission determines that this affidavit-based process for seeking confidential treatment for the information is no longer necessary, the Commission may enter an order to that effect. Notwithstanding any such order, in the event the Commission makes such a determination, nothing in this subsection (i) prevents an alternative gas supplier desiring confidential treatment for such information from filing a formal petition with the Commission seeking confidential treatment for such information.

(Source: P.A. 101-590, eff. 1-1-20; 102-958, eff. 1-1-23.)

(220 ILCS 5/19-111)

Sec. 19-111. Material changes in business.

(a) The provisions of this Section shall apply only to alternative gas suppliers serving or seeking to serve residential or small commercial customers and only to the extent such alternative gas suppliers provide services to residential or small commercial customers.

(b) Alternative gas suppliers shall file with the Commission a notification of any material change to the information supplied in a certification application within 30 days of such material change.

(1) An alternative gas supplier shall file such notice under the docket number assigned to the alternative gas supplier's certification application, whichever is the most recent. The supplier shall also serve such notice upon the gas utility company serving customers in the service area where the alternative gas supplier is certified to provide service.

(2) After notice and an opportunity for a hearing, the Commission may (i) suspend, rescind, or conditionally rescind an alternative gas supplier's certificate if it determines that the material change will adversely affect the alternative gas supplier's fitness or ability to provide the services for which it is certified or (ii) require the alternative gas supplier to provide reasonable financial assurances sufficient to protect their customers and gas utilities from default.

(c) Material changes to the information contained in or supplied with a certification application include, but are not limited to, the following:

(1) Any significant change in ownership (an ownership interest of 5% or more) of the applicant or alternative gas supplier.

(2) An affiliation with any gas utility or change of an affiliation with a gas utility in this State.

(3) Retirement or other long-term changes to the operational status of supply resources relied upon by the alternative gas supplier to provide alternative gas service. Changes in the volume of supply from any given supply resource replaced by a comparable supply resource do not need to be reported.

(4) Revocation, restriction, or termination of any interconnection or service agreement with a pipeline company or natural gas company relied upon by an alternative gas supplier to provide alternative retail natural gas service, but only if such revocation, restriction, or termination creates a situation in which the alternative gas supplier does not meet the tariffed capacity requirements of the relevant Illinois natural gas utility or utilities.

(5) If the alternative gas supplier has a long-term bond rating from Standard & Poor's or its successor, or Fitch Ratings or its successor, or Moody's Investor Service or its successor, and the alternative gas supplier's long-term bond rating falls below BBB as reported by Standard & Poor's or its successor or Fitch Ratings or its successor or below Baa3 as reported by Moody's Investors Service or its successor.

(6) The applicant or alternative gas supplier has or intends to file for reorganization, protection from creditors, or any other form of bankruptcy with any court.

(7) Any judgment, finding, or ruling by a court or regulatory agency that could affect an alternative gas supplier's fitness or ability to provide service in this State.

(8) Any change in the alternative gas supplier's name or logo, including without limitation any change in the alternative gas supplier's legal name, fictitious names, or assumed business names, except for logos and names the alternative gas supplier provided as part of its original certification process or that the alternative gas supplier previously provided to the Commission under this Section.

(Source: P.A. 95-1051, eff. 4-10-09.)

(220 ILCS 5/19-112)

Sec. 19-112. Managerial resources.

(a) An alternative gas supplier must maintain sufficient managerial resources and abilities to provide the service for which it has a certificate of service authority. In determining the level of managerial resources and abilities that the alternative gas supplier must demonstrate, the Commission shall consider, in addition to the requirements in Section 19-110(e)(1), the following:

(1) complaints to the Commission by consumers regarding the alternative gas supplier, including those that reflect on the alternative gas supplier's ability to properly manage solicitation and authorization; and

(2) the alternative gas supplier's involvement in the Commission's consumer complaint process, including the resources the alternative gas supplier dedicates to the process and the alternative gas supplier's ability to manage the issues raised by complaints, and the resolutions of the complaints.

(b) The provisions of this Section shall apply only to alternative gas suppliers serving or seeking to serve residential or small commercial customers and only to the extent such alternative gas suppliers provide services to residential or small commercial customers, unless otherwise noted.

(Source: P.A. 95-1051, eff. 4-10-09; 96-1000, eff. 7-2-10.)

(220 ILCS 5/19-115)

Sec. 19-115. Obligations of alternative gas suppliers.

(a) The provisions of this Section shall apply only to alternative gas suppliers serving or seeking to serve residential or small commercial customers and only to the extent such alternative gas suppliers provide services to residential or small commercial customers.

(b) An alternative gas supplier:

(1) shall comply with the requirements imposed on public utilities by Sections 8-201 through 8-207, 8-301, 8-505 and 8-507 of this Act, to the extent that these Sections have application to the services being offered by the alternative gas supplier;

(2) shall continue to comply with the requirements for certification stated in Section 19-110;

(3) shall comply with complaint procedures established by the Commission;

(4) except as provided in subsection (h) of this Section, shall file with the Chief Clerk of the Commission, within 20 business days after the effective date of this amendatory Act of the 95th General Assembly, a copy of bill formats, standard customer contract and customer complaint and resolution procedures, and the name and telephone number of the company representative whom Commission employees may contact to resolve customer complaints and other matters. In the case of a gas supplier that engages in door-to-door solicitation, the company shall file with the Commission the consumer information disclosure required by item (3) of subsection (c) of Section 2DDD of the Consumer Fraud and Deceptive Business Practices Act and shall file updated information within 10 business days after changes in any of the documents or information required to be filed by this item (4);

(5) shall maintain a customer call center where customers can reach a representative and receive current information. At least once every 6 months, each alternative gas supplier shall provide written information to customers explaining how to contact the call center. The average answer time for calls placed to the call center shall not exceed 60 seconds where a representative or automated system is ready to render assistance and/or accept information to process calls. The abandon rate for calls placed to the call center shall not exceed 10%. Each alternative gas supplier shall maintain records of the call center's telephone answer time performance and abandon call rate. These records shall be kept for a minimum of 2 years and shall be made available to Commission personnel upon request. In the event that answer times and/or abandon rates exceed the limits established above, the reporting alternative gas supplier may provide the Commission or its personnel with explanatory details. At a minimum, these records shall contain the following information in monthly increments:

(A) total number of calls received;

(B) number of calls answered;

(C) average answer time;

(D) number of abandoned calls; and

(E) abandon call rate.

Alternative gas suppliers that do not have electronic answering capability that meets these requirements shall notify the Manager of the Commission's Consumer Services Division or its successor within 30 days following the effective date of this amendatory Act of the 95th General Assembly and work with Staff to develop individualized reporting requirements as to the call volume and responsiveness of the call center.

On or before March 1 of every year, each entity shall file a report with the Chief Clerk of the Commission for the preceding calendar year on its answer time and abandon call rate for its call center. A copy of the report shall be sent to the Manager of the Consumer Services Division or its successor;

(6) by January 1, 2020 and every September 30 thereafter, shall submit to the Commission and the Office of the Attorney General the rates the alternative gas supplier charged to residential customers in the prior year, including each distinct rate charged and whether the rate was a fixed or variable rate, the basis for the variable rate, and any fees charged in addition to the supply rate, including monthly fees, flat fees, or other service charges; and

(7) shall make publicly available on its website, without the need for a customer login, rate information for all of its variable, time-of-use, and fixed rate contracts currently available to residential customers, including but not limited to, fixed monthly charges, early termination fees, and per therm charges.

(c) An alternative gas supplier shall not submit or execute a change in a customer's selection of a natural gas provider unless and until (i) the alternative gas supplier first discloses all material terms and conditions of the offer, including price, to the customer; (ii) the alternative gas supplier has obtained the customer's express agreement to accept the offer after the disclosure of all material terms and conditions of the offer; and (iii) the alternative gas supplier has confirmed the request for a change in accordance with one of the following procedures:

(1) The alternative gas supplier has obtained the customer's written or electronically signed authorization in a form that meets the following requirements:

(A) An alternative gas supplier shall obtain any necessary written or electronically signed authorization from a customer for a change in natural gas service by using a letter of agency as specified in this Section. Any letter of agency that does not conform with this Section is invalid.

(B) The letter of agency shall be a separate document (or an easily separable document containing only the authorization language described in item (E) of this paragraph (1)) whose sole purpose is to authorize a natural gas provider change. The letter of agency must be signed and dated by the customer requesting the natural gas provider change.

(C) The letter of agency shall not be combined with inducements of any kind on the same document.

(D) Notwithstanding items (A) and (B) of this paragraph (1), the letter of agency may be combined with checks that contain only the required letter of agency language prescribed in item (E) of this paragraph (1) and the necessary information to make the check a negotiable instrument. The letter of agency check shall not contain any promotional language or material. The letter of agency check shall contain in easily readable, bold face type on the face of the check a notice that the consumer is authorizing a natural gas provider change by signing the check. The letter of agency language also shall be placed near the signature line on the back of the check.

(E) At a minimum, the letter of agency must be printed with a print of sufficient size to be clearly legible and must contain clear and unambiguous language that confirms:

(i) the customer's billing name and address;

(ii) the decision to change the natural gas provider from the current provider to the prospective alternative gas supplier;

(iii) the terms, conditions, and nature of the service to be provided to the customer, including, but not limited to, the rates for the service contracted for by the customer; and

(iv) that the customer understands that any natural gas provider selection the customer chooses may involve a charge to the customer for changing the customer's natural gas provider.

(F) Letters of agency shall not suggest or require that a customer take some action in order to retain the customer's current natural gas provider.

(G) If any portion of a letter of agency is translated into another language, then all portions of the letter of agency must be translated into that language.

(2) An appropriately qualified independent third party has obtained, in accordance with the procedures set forth in this paragraph (2), the customer's oral authorization to change natural gas providers that confirms and includes appropriate verification data. The independent third party must (i) not be owned, managed, controlled, or directed by the alternative gas supplier or the alternative gas supplier's marketing agent; (ii) not have any financial incentive to confirm provider change requests for the alternative gas supplier or the alternative gas supplier's marketing agent; and (iii) operate in a location physically separate from the alternative gas supplier or the alternative gas supplier's marketing agent. Automated third-party verification systems and 3-way conference calls may be used for verification purposes so long as the other requirements of this paragraph (2) are satisfied. An alternative gas supplier or alternative gas supplier's sales representative initiating a 3-way conference call or a call through an automated verification system must drop off the call once the 3-way connection has been established. All third-party verification methods shall elicit, at a minimum, the following information:

(A) the identity of the customer;

(B) confirmation that the person on the call is authorized to make the provider change;

(C) confirmation that the person on the call wants to make the provider change;

(D) the names of the providers affected by the change;

(E) the service address of the service to be switched; and

(F) the price of the service to be provided and the material terms and conditions of the service being offered, including whether any early termination fees apply.

Third-party verifiers may not market the alternative gas supplier's services by providing additional information. All third-party verifications shall be conducted in the same language that was used in the underlying sales transaction and shall be recorded in their entirety. Submitting alternative gas suppliers shall maintain and preserve audio records of verification of customer authorization for a minimum period of 2 years after obtaining the verification. Automated systems must provide customers with an option to speak with a live person at any time during the call.

(3) The alternative gas supplier has obtained the customer's authorization via an automated verification system to change natural gas service via telephone. An automated verification system is an electronic system that, through pre-recorded prompts, elicits voice responses, touchtone responses, or both, from the customer and records both the prompts and the customer's responses. Such authorization must elicit the information in paragraph (2)(A) through (F) of this subsection (c). Alternative gas suppliers electing to confirm sales electronically through an automated verification system shall establish one or more toll-free telephone numbers exclusively for that purpose. Calls to the number or numbers shall connect a customer to a voice response unit, or similar mechanism, that makes a date-stamped, time-stamped recording of the required information regarding the alternative gas supplier change.

The alternative gas supplier shall not use such electronic authorization systems to market its services.

(4) When a consumer initiates the call to the prospective alternative gas supplier, in order to enroll the consumer as a customer, the prospective alternative gas supplier must, with the consent of the customer, make a date-stamped, time-stamped audio recording that elicits, at a minimum, the following information:

(A) the identity of the customer;

(B) confirmation that the person on the call is authorized to make the provider change;

(C) confirmation that the person on the call wants to make the provider change;

(D) the names of the providers affected by the change;

(E) the service address of the service to be switched; and

(F) the price of the service to be supplied and the material terms and conditions of the service being offered, including whether any early termination fees apply.

Submitting alternative gas suppliers shall maintain and preserve the audio records containing the information set forth above for a minimum period of 2 years.

(5) In the event that a customer enrolls for service from an alternative gas supplier via an Internet website, the alternative gas supplier shall obtain an electronically signed letter of agency in accordance with paragraph (1) of this subsection (c) and any customer information shall be protected in accordance with all applicable statutes and regulations. In addition, an alternative gas supplier shall provide the following when marketing via an Internet website:

(A) The Internet enrollment website shall, at a minimum, include:

(i) a copy of the alternative gas supplier's customer contract that clearly and conspicuously discloses all terms and conditions; and

(ii) a conspicuous prompt for the customer to print or save a copy of the contract.

(B) Any electronic version of the contract shall be identified by version number, in order to ensure the ability to verify the particular contract to which the customer assents.

(C) Throughout the duration of the alternative gas supplier's contract with a customer, the alternative gas supplier shall retain and, within 3 business days of the customer's request, provide to the customer an e-mail, paper, or facsimile of the terms and conditions of the numbered contract version to which the customer assents.

(D) The alternative gas supplier shall provide a mechanism by which both the submission and receipt of the electronic letter of agency are recorded by time and date.

(E) After the customer completes the electronic letter of agency, the alternative gas supplier shall disclose conspicuously through its website that the customer has been enrolled, and the alternative gas supplier shall provide the customer an enrollment confirmation number.

(6) When a customer is solicited in person by the alternative gas supplier's sales agent, the alternative gas supplier may only obtain the customer's authorization to change natural gas service through the method provided for in paragraph (2) of this subsection (c).

Alternative gas suppliers must be in compliance with this subsection (c) within 90 days after the effective date of this amendatory Act of the 95th General Assembly.

(d) Complaints may be filed with the Commission under this Section by a customer whose natural gas service has been provided by an alternative gas supplier in a manner not in compliance with subsection (c) of this Section. If, after notice and hearing, the Commission finds that an alternative gas supplier has violated subsection (c), then the Commission may in its discretion do any one or more of the following:

(1) Require the violating alternative gas supplier to refund the customer charges collected in excess of those that would have been charged by the customer's authorized natural gas provider.

(2) Require the violating alternative gas supplier to pay to the customer's authorized natural gas provider the amount the authorized natural gas provider would have collected for natural gas service. The Commission is authorized to reduce this payment by any amount already paid by the violating alternative gas supplier to the customer's authorized natural gas provider.

(3) Require the violating alternative gas supplier to pay a fine of up to $1,000 into the Public Utility Fund for each repeated and intentional violation of this Section.

(4) Issue a cease and desist order.

(5) For a pattern of violation of this Section or for intentionally violating a cease and desist order, revoke the violating alternative gas supplier's certificate of service authority.

(e) No alternative gas supplier shall:

(1) enter into or employ any arrangements which have the effect of preventing any customer from having access to the services of the gas utility in whose service area the customer is located;

(2) charge customers for such access;

(3) bill for goods or services not authorized by the customer; or

(4) bill for a disputed amount where the alternative gas supplier has been provided notice of such dispute. The supplier shall attempt to resolve a dispute with the customer. When the dispute is not resolved to the customer's satisfaction, the supplier shall inform the customer of the right to file an informal complaint with the Commission and provide contact information. While the pending dispute is active at the Commission, an alternative gas supplier may bill only for the undisputed amount until the Commission has taken final action on the complaint.

(f) An alternative gas supplier that is certified to serve residential or small commercial customers shall not:

(1) deny service to a customer or group of customers nor establish any differences as to prices, terms, conditions, services, products, facilities, or in any other respect, whereby such denial or differences are based upon race, gender, or income, except as provided in Section 19-116;

(2) deny service based on locality, nor establish any unreasonable difference as to prices, terms, conditions, services, products, or facilities as between localities;

(3) include in any agreement a provision that obligates a customer to the terms of the agreement if the customer (i) moves outside the State of Illinois; (ii) moves to a location without a transportation service program; or (iii) moves to a location where the customer will not require natural gas service, provided that nothing in this subsection precludes an alternative gas supplier from taking any action otherwise available to it to collect a debt that arises out of service provided to the customer before the customer moved; or

(4) assign the agreement to any alternative natural gas supplier, unless:

(A) the supplier is an alternative gas supplier certified by the Commission;

(B) the rates, terms, and conditions of the agreement being assigned do not change during the remainder of the time covered by the agreement;

(C) the customer is given no less than 30 days prior written notice of the assignment and contact information for the new supplier; and

(D) the supplier assigning the contract provides contact information that a customer can use to resolve a dispute.

(g) An alternative gas supplier shall comply with the following requirements with respect to the marketing, offering, and provision of products or services:

(1) All marketing materials, including, but not limited to, electronic marketing materials, in-person solicitations, and telephone solicitations, concerning prices, terms, and conditions of service shall contain information that adequately discloses the prices, terms, and conditions of the products or services and shall disclose the utility gas supply cost rates per therm price available from the Illinois Commerce Commission website applicable at the time the alternative gas supplier is offering or selling the products or services to the customer and shall disclose the date on which the utility gas supply cost rates per therm became effective and the date on which they will expire. All marketing materials, including, but not limited to, electronic marketing materials, in-person solicitations, and telephone solicitations, shall include the following statement:

"(Name of the alternative gas supplier) is not the same entity as your gas delivery company. You are not required to enroll with (name of alternative gas supplier). Beginning on (effective date), the utility gas supply cost rate per therm is (cost). The utility gas supply cost will expire on (expiration date). For more information go to the Illinois Commerce Commission's free website at www.icc.illinois.gov/ags/consumereducation.aspx.".

This paragraph (1) does not apply to goodwill or institutional advertising.

(2) Before any customer is switched from another supplier, the alternative gas supplier shall give the customer written information that clearly and conspicuously discloses, in plain language, the prices, terms, and conditions of the products and services being offered and sold to the customer. This written information shall be provided in a language in which the customer subject to the marketing or solicitation is able to understand and communicate, and the alternative gas supplier shall not switch a customer who is unable to understand and communicate in a language in which the marketing or solicitation was conducted. The alternative gas supplier shall comply with Section 2N of the Consumer Fraud and Deceptive Business Practices Act. Nothing in this paragraph (2) may be read to relieve an alternative gas supplier from the duties imposed on it by item (3) of subsection (c) of Section 2DDD of the Consumer Fraud and Deceptive Business Practices Act.

(3) The alternative gas supplier shall provide to the customer:

(A) accurate, timely, and itemized billing statements that describe the products and services provided to the customer and their prices and that specify the gas consumption amount and any service charges and taxes; provided that this item (g)(3)(A) does not apply to small commercial customers;

(B) billing statements that clearly and conspicuously discloses the name and contact information for the alternative gas supplier;

(C) an additional statement, at least annually, that adequately discloses the average monthly prices, and the terms and conditions, of the products and services sold to the customer; provided that this item (g)(3)(C) does not apply to small commercial customers;

(D) refunds of any deposits with interest within 30 days after the date that the customer changes gas suppliers or discontinues service if the customer has satisfied all of his or her outstanding financial obligations to the alternative gas supplier at an interest rate set by the Commission which shall be the same as that required of gas utilities; and

(E) refunds, in a timely fashion, of all undisputed overpayments upon the oral or written request of the customer.

(4) An alternative gas supplier and its sales agents shall refrain from any direct marketing or soliciting to consumers on the gas utility's "Do Not Contact List", which the alternative gas supplier shall obtain on the 15th calendar day of the month from the gas utility in whose service area the consumer is provided with gas service. If the 15th calendar day is a non-business day, then the alternative gas supplier shall obtain the list on the next business day following the 15th calendar day of that month.

(5) Early Termination.

(A) Any agreement that contains an early termination clause shall disclose the amount of the early termination fee, provided that any early termination fee or penalty shall not exceed $50 total, regardless of whether or not the agreement is a multiyear agreement.

(B) In any agreement that contains an early termination clause, an alternative gas supplier shall provide the customer the opportunity to terminate the agreement without any termination fee or penalty within 10 business days after the date of the first bill issued to the customer for products or services provided by the alternative gas supplier. The agreement shall disclose the opportunity and provide a toll-free phone number that the customer may call in order to terminate the agreement. Beginning January 1, 2020, residential and small commercial customers shall have a right to terminate their agreements with alternative gas suppliers at any time without any termination fees or penalties.

(6) Within 2 business days after electronic receipt of a customer switch from the alternative gas supplier and confirmation of eligibility, the gas utility shall provide the customer written notice confirming the switch. The gas utility shall not switch the service until 10 business days after the date on the notice to the customer.

(7) The alternative gas supplier shall provide each customer the opportunity to rescind its agreement without penalty within 10 business days after the date on the gas utility notice to the customer. The alternative gas supplier shall disclose all of the following:

(A) that the gas utility shall send a notice confirming the switch;

(B) that from the date the utility issues the notice confirming the switch, the customer shall have 10 business days to rescind the switch without penalty;

(C) that the customer shall contact the gas utility or the alternative gas supplier to rescind the switch; and

(D) the contact information for the gas utility.

The alternative gas supplier disclosure shall be included in its sales solicitations, contracts, and all applicable sales verification scripts.

(8) All in-person and telephone solicitations shall be conducted in, translated into, and provided in a language in which the consumer subject to the marketing or solicitation is able to understand and communicate. An alternative gas supplier shall terminate a solicitation if the consumer subject to the marketing or communication is unable to understand and communicate in the language in which the marketing or solicitation is being conducted. An alternative gas supplier shall comply with Section 2N of the Consumer Fraud and Deceptive Business Practices Act.

(h) An alternative gas supplier may limit the overall size or availability of a service offering by specifying one or more of the following:

(1) a maximum number of customers and maximum amount of gas load to be served;

(2) time period during which the offering will be available; or

(3) other comparable limitation, but not including the geographic locations of customers within the area which the alternative gas supplier is certificated to serve.

The alternative gas supplier shall file the terms and conditions of such service offering including the applicable limitations with the Commission prior to making the service offering available to customers.

(i) Nothing in this Section shall be construed as preventing an alternative gas supplier that is an affiliate of, or which contracts with, (i) an industry or trade organization or association, (ii) a membership organization or association that exists for a purpose other than the purchase of gas, or (iii) another organization that meets criteria established in a rule adopted by the Commission from offering through the organization or association services at prices, terms and conditions that are available solely to the members of the organization or association.

(Source: P.A. 101-590, eff. 1-1-20; 102-459, eff. 8-20-21.)

(220 ILCS 5/19-116)

Sec. 19-116. Alternative gas supplier utility assistance recipient.

(a) Beginning January 1, 2020, an alternative gas supplier shall not knowingly submit an enrollment to change a customer's natural gas supplier if the gas utility's records indicate that the customer received financial assistance in the previous 12 months from either the Low Income Home Energy Assistance Program or, at the time of enrollment is participating in the Percentage of Income Payment Plan, unless the customer's change in gas supplier is pursuant to a Commission-approved savings guarantee plan as described in subsection (b).

(b) Beginning January 1, 2020, an alternative gas supplier may apply to the Commission to offer a savings guarantee plan to recipients of Low Income Home Energy Assistance Program funding or Percentage of Income Payment Plan funding. The Commission shall initiate a public, docketed proceeding to consider whether or not to approve an alternative gas supplier's application to offer a savings guarantee plan. At a minimum, the savings guarantee plan shall charge customers for natural gas supply at an amount that is less than the amount charged by the gas utility.

(c) An agreement entered into between an alternative gas supplier and a customer in violation of this Section is void and unenforceable. Before the gas utility executes a change in a customer's natural gas supplier, other than a change pursuant to a Commission-approved savings guarantee plan as described in subsection (b), the gas utility shall confirm at the time of the request whether its records indicate that the customer has either received financial assistance from the Low Income Home Energy Assistance Program within the previous 12 months, or, at the time of enrollment is participating in the Percentage of Income Payment Plan; and if so, shall reject such change request. Absent willful or wanton misconduct, no gas utility shall be held liable for any error in acting or failing to act pursuant to this Section.

(Source: P.A. 101-590, eff. 1-1-20.)

(220 ILCS 5/19-120)

Sec. 19-120. Commission oversight of services provided by gas suppliers.

(a) The provisions of this Section shall apply only to alternative gas suppliers serving or seeking to serve residential or small commercial customers and only to the extent such alternative gas suppliers provide services to residential or small commercial customers.

(b) The Commission shall have jurisdiction in accordance with the provisions of Article X of this Act either to investigate on its own motion in order to determine whether or to entertain and dispose of any complaint by any person or corporation, chamber of commerce, board of trade, or any industrial, commercial, mercantile, agricultural or manufacturing society, or any body politic or municipal corporation against any alternative gas supplier alleging that:

(1) the alternative gas supplier has violated or is in nonconformance with any applicable provisions of Section 19-110, 19-111, 19-112, or Section 19-115;

(1.5) that the alternative retail gas supplier violated any rule adopted by the Commission to govern the sales, marketing, or operations of retail gas suppliers;

(2) an alternative gas supplier has failed to provide service in accordance with the terms of its contract or contracts with a customer or customers;

(3) the alternative gas supplier has violated or is in nonconformance with the transportation services tariff of, or any of its agreements relating to transportation services with, the gas utility or municipal system providing transportation services; or

(4) the alternative gas supplier has violated or failed to comply with the requirements of Sections 8-201 through 8-207, 8-301, 8-505, or 8-507 of this Act as made applicable to alternative gas suppliers.

(c) The Commission shall have authority after such administrative notice as is required by the Illinois Administrative Procedure Act and after an administrative hearing held on complaint or on the Commission's own motion to order any or all of the following remedies, penalties, or forms of relief:

(1) order an alternative gas supplier to cease and desist, or correct, any violation of or nonconformance with the provisions of Section 19-110, 19-111, 19-112, or 19-115, or any violation or nonconformance over which the Commission has jurisdiction under subsection (a) of Section 19-120;

(2) impose financial penalties for violations of or nonconformances with the provisions of Section 19-110, 19-111, 19-112, or 19-115, not to exceed $10,000 per occurrence, and for any violations or nonconformances that continue after the Commission issues a cease and desist order, up to an additional $30,000 for each day the violations or nonconformances continue; and

(3) alter, modify, revoke, or suspend the certificate of service authority of an alternative gas supplier for substantial or repeated violations of or nonconformances with the provisions of Section 19-110, 19-111, 19-112, or 19-115.

(d) Nothing in this Act shall be construed to limit, restrict, or mitigate in any way the power and authority of the State's Attorneys or the Attorney General under the Consumer Fraud and Deceptive Business Practices Act.

(e) In addition to other powers and authority granted to it under this Act, the Commission may require an alternative gas supplier to enter into a compliance plan. If the Commission comes into possession of information causing it to conclude that an alternative gas supplier is violating this Act or the Commission's rules, the Commission may, after notice and hearing, enter an order directing the alternative gas supplier to implement practices, procedures, oversight, or other measures or refrain from practices, conduct, or activities as the Commission finds is necessary or reasonable to ensure the alternative gas supplier's compliance with this Act and the Commission's rules. Failure by an alternative gas supplier to implement or comply with a Commission-ordered compliance plan is a violation of this Section. The Commission, in its discretion, may order a compliance plan under such circumstances as it considers warranted and is not required to order a compliance plan prior to taking other enforcement action against an alternative retail gas supplier. Nothing in this subsection (e) shall be interpreted to limit the authority or right of the Attorney General.

(Source: P.A. 101-590, eff. 1-1-20; 102-958, eff. 1-1-23.)

(220 ILCS 5/19-125)

Sec. 19-125. Consumer education.

(a) The Commission shall make available upon request and at no charge, and shall make available to the public on the Internet through the State of Illinois World Wide Web site:

(1) a list of all certified alternative gas suppliers serving residential and small commercial customers within the service area of each gas utility including, in the case of the Internet, computer links to available web sites of the certified alternative gas suppliers;

(2) a list of all certified alternative gas suppliers serving residential or small commercial customers that have been found in the last 3 years by the Commission pursuant to Section 10-108 to have failed to provide service in accordance with this Act;

(3) guidelines to assist customers in determining which gas supplier is most appropriate for each customer; and

(4) Internet links to providers of information that enables customers to compare prices and services of gas utilities and alternative gas suppliers, if and when that information is available.

(a-5) The Commission shall develop no later than 6 months after the effective date of this amendatory Act of the 95th General Assembly and maintain consumer education information to help residential and small commercial consumers understand their gas supply options and their rights and responsibilities. The Commission shall publish the consumer education information on its World Wide Web site.

(a-10) To assist the Commission in developing consumer education information, the Commission shall form a working group that shall consist of representatives of gas utilities with residential and small commercial gas transportation service programs, alternative gas suppliers, the Attorney General, the Citizens Utility Board, and the Commission.

(a-15) At a minimum, the consumer education information developed by the Commission shall include explanations or descriptions of the following:

(1) The choices available to consumers to take gas service from an alternative retail gas supplier or remain as a retail customer of the gas utility.

(2) A consumer's rights and responsibilities in receiving service from an alternative retail gas supplier or remaining as a retail customer of the gas utility.

(3) The gas utility's role in delivering gas, including, but not limited to, utility response to calls for service and gas leaks.

(4) The legal obligations of alternative retail gas suppliers.

(5) The components of a bill that could be received by a customer taking delivery services.

(6) The procedures available to customers to address complaints against a gas utility or an alternative retail gas supplier and a list of phone numbers and other contact information for the Commission, the Attorney General, or the Citizens Utility Board.

(7) Guidance to assist consumers in making educated decisions when choosing their natural gas provider, including:

(A) how to compare prices;

(B) questions to ask when considering natural gas providers; and

(C) current and historical utility gas rates.

(8) The availability of the "Do Not Contact List" for those who do not wish to be solicited by natural gas providers.

(b) In any service area where customers are able to choose their natural gas supplier, the Commission shall require gas utilities and alternative gas suppliers to inform customers of how they may contact the Commission in order to obtain information about the customer choice program.

(c) The Commission shall adopt a uniform disclosure that alternative gas suppliers shall be required to complete for each product offering. The uniform disclosure shall contain, at a minimum:

(1) for products with a fixed price per therm, the price per therm;

(2) the length of the initial term of the product, or, if applicable, the expiration date of the initial term of the product;

(3) the amount of the termination fees, if any;

(4) the amount of the administrative fees, other fees, or recurring charges, if any, to be listed separately for each and every fee or charge;

(5) for products with a variable price per therm, the terms of such variability, including, but not limited to, any index that is used to calculate the price and any additional charges, costs and fees; and

(6) for products where a customer's charges are a fixed amount per billing period regardless of the market price for natural gas or the customer's natural gas consumption during the billing period, the billing period covered.

If the alternative gas supplier will not offer a different product for new customers as of the first of the month, then the alternative gas supplier does not have to provide new information until the first day of the month in which a different product or products are being offered.

The Commission shall post this information on its World Wide Web site in a manner that shall enable customers to compare prices, terms, and conditions offered by the alternative gas suppliers. The website shall be updated at least monthly and the Commission shall maintain this information on its website for at least 12 months to allow customers to compare the historical plans and prices for all alternative gas suppliers.

(d) The Commission shall make available in print, upon request and at no charge and on its World Wide Web site, information on which customers of alternative gas suppliers serving residential and small commercial customers may address any complaint with regard to an alternative gas supplier's obligations under Section 19-115 of this Article, including the provision of service in accordance with the terms of its contract, sales tactics, and rates. The Commission shall maintain a summary by category and provider of all formal and informal complaints it receives pursuant to this Section, and it shall publish the summary on a quarterly basis on its World Wide Web site. Individual customer information shall not be included in the summary.

(e) The provisions of this Section shall apply only to alternative gas suppliers serving or seeking to serve residential and small commercial customers and only to the extent such alternative gas suppliers provide services to residential and small commercial customers.

(Source: P.A. 95-1051, eff. 4-10-09.)

(220 ILCS 5/19-130)

Sec. 19-130. Commission study and report. The Commission's Office of Retail Market Development shall prepare an annual report regarding the development of competitive retail natural gas markets in Illinois. The Office shall monitor existing competitive conditions in Illinois, identify barriers to retail competition for all customer classes, and actively explore and propose to the Commission and to the General Assembly solutions to overcome identified barriers. Solutions proposed by the Office to promote retail competition must also promote safe, reliable, and affordable natural gas service.

On or before October 31 of each year, the Director shall submit a report to the Commission, the General Assembly, and the Governor, that includes, at a minimum, the following information:

(1) an analysis of the status and development of the retail natural gas market in the State of Illinois; and

(2) a discussion of any identified barriers to the development of competitive retail natural gas markets in Illinois and proposed solutions to overcome identified barriers; and

(3) any other information the Office considers significant in assessing the development of natural gas markets in the State of Illinois.

Beginning in 2021, the report shall also include the information submitted to the Commission pursuant to paragraph (6) of subsection (b) of Section 19-115.

(Source: P.A. 101-590, eff. 1-1-20; 102-459, eff. 8-20-21.)

(220 ILCS 5/19-135)

Sec. 19-135. Single billing.

(a) It is the intent of the General Assembly that in any service area where customers are able to choose their natural gas supplier, a single billing option shall be offered to customers for both the services provided by the alternative gas supplier and the delivery services provided by the gas utility. A gas utility shall file a tariff pursuant to Article IX of this Act that allows alternative gas suppliers to issue single bills to residential and small commercial customers for both the services provided by the alternative gas supplier and the delivery services provided by the gas utility to customers; provided that if a form of single billing is being offered in a gas utility's service area on the effective date of this amendatory Act of the 92nd General Assembly, that form of single billing shall remain in effect unless and until otherwise ordered by the Commission.

(b) Every alternative gas supplier that issues a single bill for delivery and supply shall include on the single bill issued to a residential customer the current utility gas supply cost rate per therm that would apply to the customer for the billing period if the customer obtained supply from the utility, including all fixed or monthly supply charges and other charges, credits, or rates that are part of the gas supply price.

(c) Every gas utility that offers supply choice and provides delivery and alternative gas supply service on a single bill to its residential customers shall include on the bill of each residential customer who purchases supply services from an alternative gas supplier the current utility gas supply cost rate per therm that would apply to the customer for the billing period if the customer obtained supply from the utility, including all fixed or monthly supply charges and other charges, credits, or rates that are part of the gas supply price.

(Source: P.A. 101-590, eff. 1-1-20.)

(220 ILCS 5/19-140)

Sec. 19-140. On-bill financing program; gas utilities.

(a) The Illinois General Assembly finds that Illinois homes and businesses have the potential to save energy through conservation and cost-effective energy efficiency measures. Programs created pursuant to this Section will allow utility customers to purchase cost-effective energy efficiency measures, including measures set forth in a Commission-approved energy efficiency plan under Section 8-104 of this Act, with no required initial upfront payment, and to pay the cost of those products and services over time on their utility bill.

(b) Notwithstanding any other provision of this Act, a gas utility serving more than 100,000 customers on January 1, 2009 shall offer a Commission-approved on-bill financing program ("program") that allows its retail customers who own a residential single family home, duplex, or other residential building with 4 or less units, or condominium at which the gas service is being provided (i) to borrow funds from a third party lender in order to purchase gas energy efficiency measures approved under the program for installation in such home or condominium without any required upfront payment and (ii) to pay back such funds over time through the gas utility's bill. Based upon the process described in subsection (b-5) of this Section, small commercial customers who own the premises at which gas service is being provided may be included in such program. After receiving a request from a gas utility for approval of a proposed program and tariffs pursuant to this Section, the Commission shall render its decision within 120 days. If no decision is rendered within 120 days, then the request shall be deemed to be approved. Beginning no later than December 31, 2013, a gas utility subject to this subsection (b) shall also offer its program to eligible retail customers that own a multifamily residential or mixed-use building with no more than 50 residential units, provided, however, that such customer must either be a residential customer or small commercial customer and may not use the program in such a way that repayment of the cost of energy efficiency measures is made through tenants' utility bills. A gas utility may impose a per site loan limit not to exceed $150,000. The program, and loans issued thereunder, shall only be offered to customers of the utility that meet the requirements of this Section and that also have a gas service account at the premises where the energy efficiency measures being financed shall be installed.

For purposes of this Section, a small commercial customer for a gas utility shall be defined in that gas utility's informational filing that is made under subsection (c-5) of this Section.

(b-5) Within 30 days after the effective date of this amendatory Act of the 96th General Assembly, the Commission shall convene a workshop process during which interested participants may discuss issues related to the program, including program design, eligible gas energy efficiency measures, vendor qualifications, and a methodology for ensuring ongoing compliance with such qualifications, financing, sample documents such as request for proposals, contracts and agreements, dispute resolution, pre-installment and post-installment verification, and evaluation. The workshop process shall be completed within 150 days after the effective date of this amendatory Act of the 96th General Assembly.

(c) Not later than 60 days following completion of the workshop process described in subsection (b-5) of this Section, each gas utility subject to subsection (b) of this Section shall submit a proposed program to the Commission that contains the following components:

(1) A list of recommended gas energy efficiency measures that will be eligible for on-bill financing. An eligible gas energy efficiency measure ("measure") shall be a product or service for which one or more of the following is true:

(A) (blank);

(B) the projected gas savings (determined by rates in effect at the time of purchase) are sufficient to cover the costs of implementing the measures, including finance charges and any program fees not recovered pursuant to subsection (f) of this Section; or

(C) the product or service is included in a Commission-approved energy efficiency plan under Section 8-104 of this Act.

(2) The gas utility shall issue a request for proposals ("RFP") to lenders for purposes of providing financing to participants to pay for approved measures. The RFP criteria shall include, but not be limited to, the interest rate, origination fees, and credit terms. The utility shall select the winning bidders based on its evaluation of these criteria, with a preference for those bids containing the rates, fees, and terms most favorable to participants.

(3) The utility shall work with the lenders selected pursuant to the RFP process, and with vendors, to establish the terms and processes pursuant to which a participant can purchase eligible gas energy efficiency measures using the financing obtained from the lender. The vendor shall explain and offer the approved financing packaging to those customers identified in subsection (b) of this Section and shall assist customers in applying for financing. As part of such process, vendors shall also provide to participants information about any other incentives that may be available for the measures.

(4) The lender shall conduct credit checks or undertake other appropriate measures to limit credit risk, and shall review and approve or deny financing applications submitted by customers identified in subsection (b) of this Section. Following the lender's approval of financing and the participant's purchase of the measure or measures, the lender shall forward payment information to the gas utility, and the utility shall add as a separate line item on the participant's utility bill a charge showing the amount due under the program each month.

(5) A loan issued to a participant pursuant to the program shall be the sole responsibility of the participant, and any dispute that may arise concerning the loan's terms, conditions, or charges shall be resolved between the participant and lender. Upon transfer of the property title for the premises at which the participant receives gas service from the utility or the participant's request to terminate service at such premises, the participant shall pay in full its gas utility bill, including all amounts due under the program, provided that this obligation may be modified as provided in subsection (g) of this Section. Amounts due under the program shall be deemed amounts owed for residential and, as appropriate, small commercial gas service.

(6) The gas utility shall remit payment in full to the lender each month on behalf of the participant. In the event a participant defaults on payment of its gas utility bill, the gas utility shall continue to remit all payments due under the program to the lender, and the utility shall be entitled to recover all costs related to a participant's nonpayment through the automatic adjustment clause tariff established pursuant to Section 19-145 of this Act. In addition, the gas utility shall retain a security interest in the measure or measures purchased under the program, and the utility retains its right to disconnect a participant that defaults on the payment of its utility bill.

(7) The total outstanding amount financed under the program in this subsection and subsection (c-5) of this Section shall not exceed $2.5 million for a gas utility or gas utilities under a single holding company, provided that the gas utility or gas utilities may petition the Commission for an increase in such amount.

(c-5) Within 120 days after the effective date of this amendatory Act of the 98th General Assembly, each covered gas utility shall submit an informational filing to the Commission that describes its plan for implementing the provisions of this amendatory Act of the 98th General Assembly on or before December 31, 2013. A gas utility subject to this Section shall cooperate with any electric utility that provides electric service to buildings within the gas utility's service territory so that it is practical and feasible for the owner of a multifamily building to make a single application to access loans for both gas and electric energy efficiency measures in any individual building.

(d) A program approved by the Commission shall also include the following criteria and guidelines for such program:

(1) guidelines for financing of measures installed under a program, including, but not limited to, RFP criteria and limits on both individual loan amounts and the duration of the loans;

(2) criteria and standards for identifying and approving measures;

(3) qualifications of vendors that will market or install measures, as well as a methodology for ensuring ongoing compliance with such qualifications;

(4) sample contracts and agreements necessary to implement the measures and program; and

(5) the types of data and information that utilities and vendors participating in the program shall collect for purposes of preparing the reports required under subsection (g) of this Section.

(e) The proposed program submitted by each gas utility shall be consistent with the provisions of this Section that define operational, financial, and billing arrangements between and among program participants, vendors, lenders, and the gas utility.

(f) A gas utility shall recover all of the prudently incurred costs of offering a program approved by the Commission pursuant to this Section, including, but not limited to, all start-up and administrative costs and the costs for program evaluation. All prudently incurred costs under this Section shall be recovered from the residential and small commercial retail customer classes eligible to participate in the program through the automatic adjustment clause tariff established pursuant to Section 8-104 of this Act.

(g) An independent evaluation of a program shall be conducted after 3 years of the program's operation. The gas utility shall retain an independent evaluator who shall evaluate the effects of the measures installed under the program and the overall operation of the program, including, but not limited to, customer eligibility criteria and whether the payment obligation for permanent gas energy efficiency measures that will continue to provide benefits of energy savings should attach to the meter location. As part of the evaluation process, the evaluator shall also solicit feedback from participants and interested stakeholders. The evaluator shall issue a report to the Commission on its findings no later than 4 years after the date on which the program commenced, and the Commission shall issue a report to the Governor and General Assembly including a summary of the information described in this Section as well as its recommendations as to whether the program should be discontinued, continued with modification or modifications or continued without modification, provided that any recommended modifications shall only apply prospectively and to measures not yet installed or financed.

(h) A gas utility offering a Commission-approved program pursuant to this Section shall not be required to comply with any other statute, order, rule, or regulation of this State that may relate to the offering of such program, provided that nothing in this Section is intended to limit the gas utility's obligation to comply with this Act and the Commission's orders, rules, and regulations, including Part 280 of Title 83 of the Illinois Administrative Code.

(i) The source of a utility customer's gas supply shall not disqualify a customer from participation in the utility's on-bill financing program. Customers of alternative gas suppliers may participate in the program under the same terms and conditions applicable to the utility's supply customers.

(Source: P.A. 98-586, eff. 8-27-13.)

(220 ILCS 5/19-145)

Sec. 19-145. Automatic adjustment clause tariff; uncollectibles.

(a) A gas utility shall be permitted, at its election, to recover through an automatic adjustment clause tariff the incremental difference between its actual uncollectible amount as set forth in Account 904 in the utility's most recent annual Form 21 ILCC and the uncollectible amount included in the utility's rates for the period reported in such annual Form 21 ILCC. The Commission may, in a proceeding to review a general rate case filed subsequent to the effective date of the tariff established under this Section, prospectively switch, from using the actual uncollectible amount set forth in Account 904 to using net write-offs in such tariff, but only if net write-offs are also used to determine the utility's uncollectible amount in rates. In the event the Commission requires such a change, it shall be made effective at the beginning of the first full calendar year after the new rates approved in such proceeding are first placed in effect and an adjustment shall be made, if necessary, to ensure the change does not result in double-recovery or unrecovered uncollectible amounts for any year. For purposes of this Section, "uncollectible amount" means the expense set forth in Account 904 of the utility's Form 21 ILCC or cost of net write-offs as appropriate. In the event the utility's rates change during the period of time reported in its most recent annual Form 21 ILCC, the uncollectible amount included in the utility's rates during such period of time for purposes of this Section will be a weighted average, based on revenues earned during such period by the utility under each set of rates, of the uncollectible amount included in the utility's rates at the beginning of such period and at the end of such period. This difference may either be a charge or a credit to customers depending on whether the uncollectible amount is more or less than the uncollectible amount then included in the utility's rates.

(b) The tariff may be established outside the context of a general rate case filing, and shall specify the terms of any applicable audit. The Commission shall review and by order approve, or approve as modified, the proposed tariff within 180 days after the date on which it is filed. Charges and credits under the tariff shall be allocated to the appropriate customer class or classes. In addition, customers who do not purchase their gas supply from a gas utility shall not be charged by the utility for uncollectible amounts associated with gas supply provided by the utility to the utility's customers. Upon approval of the tariff, the utility shall, based on the 2008 Form 21 ILCC, apply the appropriate credit or charge based on the full year 2008 amounts for the remainder of the 2010 calendar year. Starting with the 2009 Form 21 ILCC reporting period and each subsequent period, the utility shall apply the appropriate credit or charge over a 12-month period beginning with the June billing period and ending with the May billing period, with the first such billing period beginning June 2010.

(c) The approved tariff shall provide that the utility shall file a petition with the Commission annually, no later than August 31st, seeking initiation of an annual review to reconcile all amounts collected with the actual uncollectible amount in the prior period. As part of its review, the Commission shall verify that the utility collects no more and no less than its actual uncollectible amount in each applicable Form 21 ILCC reporting period. The Commission shall review the prudence and reasonableness of the utility's actions to pursue minimization and collection of uncollectibles which shall include, at a minimum, the 6 enumerated criteria set forth in this Section. The Commission shall determine any required adjustments and may include suggestions for prospective changes in current practices. Nothing in this Section or the implementing tariffs shall affect or alter the gas utility's existing obligation to pursue collection of uncollectibles or the gas utility's right to disconnect service. A utility that has in effect a tariff authorized by this Section shall pursue minimization of and collection of uncollectibles through the following activities, including but not limited to:

(1) identifying customers with late payments;

(2) contacting the customers in an effort to obtain payment;

(3) providing delinquent customers with information about possible options, including payment plans and assistance programs;

(4) serving disconnection notices;

(5) implementing disconnections based on the level of uncollectibles; and

(6) pursuing collection activities based on the level of uncollectibles.

(d) Nothing in this Section shall be construed to require a utility to immediately disconnect service for nonpayment.

(Source: P.A. 96-33, eff. 7-10-09.)

(220 ILCS 5/Art. XX heading) ARTICLE XX. RETAIL ELECTRIC COMPETITION (Source: P.A. 94-1095, eff. 2-2-07.)

(220 ILCS 5/20-101)

Sec. 20-101. This Article may be cited as the Retail Electric Competition Act of 2006.

(Source: P.A. 94-1095, eff. 2-2-07.)

(220 ILCS 5/20-102)

Sec. 20-102. Findings and intent.

(a) A competitive wholesale electricity market alone will not deliver the full benefits of competition to Illinois consumers. For Illinois consumers to receive products, prices and terms tailored to meet their needs, a competitive wholesale electricity market must be closely linked to a competitive retail electric market.

(b) To date, as a result of the Electric Service Customer Choice and Rate Relief Law of 1997, thousands of large Illinois commercial and industrial consumers have experienced the benefits of a competitive retail electricity market. Alternative electric retail suppliers actively compete to supply electricity to large Illinois commercial and industrial consumers with attractive prices, terms, and conditions.

(c) A competitive retail electric market does not yet exist for residential and small commercial consumers. As a result, millions of residential and small commercial consumers in Illinois are faced with escalating heating and power bills and are unable to shop for alternatives to the rates demanded by the State's incumbent electric utilities.

(d) The General Assembly reiterates its findings from the Electric Service Customer Choice and Rate Relief Law of 1997 that the Illinois Commerce Commission should promote the development of an effectively competitive retail electricity market that operates efficiently and benefits all Illinois consumers.

(Source: P.A. 94-1095, eff. 2-2-07.)

(220 ILCS 5/20-105)

Sec. 20-105. Definitions. In this Article:

"Director" means the Director of the Office of Retail Market Development.

"Office" means the Office of Retail Market Development.

(Source: P.A. 94-1095, eff. 2-2-07.)

(220 ILCS 5/20-110)

Sec. 20-110. Office of Retail Market Development. Within 90 days after the effective date of this amendatory Act of the 94th General Assembly, subject to appropriation, the Commission shall establish an Office of Retail Market Development and employ on its staff a Director of Retail Market Development to oversee the Office. The Director shall have authority to employ or otherwise retain at least 2 professionals dedicated to the task of actively seeking out ways to promote retail competition in Illinois to benefit all Illinois consumers.

The Office shall actively seek input from all interested parties and shall develop a thorough understanding and critical analyses of the tools and techniques used to promote retail competition in other states.

The Office shall monitor existing competitive conditions in Illinois, identify barriers to retail competition for all customer classes, and actively explore and propose to the Commission and to the General Assembly solutions to overcome identified barriers. The Director may include municipal aggregation of customers and creating and designing customer choice programs as tools for retail market development. Solutions proposed by the Office to promote retail competition must also promote safe, reliable, and affordable electric service.

On or before July 31 of each year, the Director shall submit a report to the Commission, the General Assembly, and the Governor, that details specific accomplishments achieved by the Office in the prior 12 months in promoting retail electric competition and that suggests administrative and legislative action necessary to promote further improvements in retail electric competition. On or before July 31, 2021 and each year thereafter, the report shall include the information submitted to the Commission pursuant to paragraph (iii) of subsection (a) of Section 16-115A.

(Source: P.A. 101-590, eff. 1-1-20.)

(220 ILCS 5/20-120)

Sec. 20-120. Residential and small commercial retail electric competition. Within 12 months after the effective date of this amendatory Act of the 94th General Assembly, the Director shall conduct research, gather input from all interested parties and develop and present to the Commission, the General Assembly, and the Governor a detailed plan designed to promote, in the most expeditious manner possible, retail electric competition for residential and small commercial electricity consumers while maintaining safe, reliable, and affordable service. Interested parties shall be given the opportunity to review the plan and provide written comments regarding the plan prior to its submission to the Commission, the General Assembly, and the Governor. Any written comments received by the Office shall be posted on the Commission's web site. The final plan submitted to the Commission, the General Assembly, and the Governor must include summaries of any written comments and must also be posted on the Commission's web site.

To the extent the plan calls for Commission action, the Commission shall initiate any proceeding or proceedings called for in the final plan within 60 days after receipt of the final plan and complete those proceedings within 11 months after their initiation.

Nothing in this Section shall prevent the Commission from acting earlier to remove identified barriers to retail electric competition for residential and small commercial consumers.

(Source: P.A. 94-1095, eff. 2-2-07.)

(220 ILCS 5/20-130)

Sec. 20-130. Retail choice and referral programs.

(a) The Commission shall have the authority to establish retail choice and referral programs to be administered by an electric utility or the State in which residential and small commercial customers receive incentives, including, but not limited to, discounted rate introductory offers for switching to participating electric suppliers.

(b) Reasonable costs associated with the implementation and operation of customer choice and referral programs may be recovered in an electric utility's distribution rates, except that any costs associated with any introductory discount for switching to a supplier shall be assumed by that supplier. Reasonable costs associated with the implementation and operation of a customer choice program may also be recovered from retail electric suppliers participating in a customer choice and referral program. In no event, however, shall the Commission mandate a cost recovery mechanism without first providing all interested parties notice and an opportunity to be heard in a hearing before the Commission.

(c) The Office of Retail Market Development shall serve as the clearinghouse for the development of retail choice and referral programs and shall work with electric utilities and interested parties on a continuous basis to implement and improve upon the programs. Nothing in this Section, however, shall prevent an electric utility on its own accord from implementing retail choice and referral programs.

(d) Only customers that qualify for utility service shall be eligible for retail choice and referral programs.

(e) The Office of Retail Market Development shall immediately upon the effective date of this amendatory Act of the 95th General Assembly explore for possible implementation on as expedited a basis as possible the following retail choice and referral programs:

(1) An introductory fixed discount program in which suppliers participating in the program offer customers a fixed percentage discount off of the electric utility's supply rate for a set number of billing periods. Customers would be able to enroll in the program by using an online enrollment form, completing an enrollment card found in their monthly electric utility bill, or by calling a toll-free number. Customers would be free to withdraw from the program at any time and select another alternative retail electric supplier or return to the electric utility.

(2) A new customer program in which electric utilities would offer consumers initiating new electric service a choice of offers from participating electric suppliers to provide the consumer's electric supply service. Customers expressing a preference for a specific electric supplier would be enrolled with that supplier. Customers not expressing a preference for a specific electric supplier would be offered the opportunity to enroll with an electric supplier selected randomly on a rotating basis.

(3) A customer service call center referral program in which customers calling an electric utility's call center would be offered enrollment with an alternative retail electric supplier and informed that they have the option to receive immediate savings or introductory offers by participating in the referral program. Customers choosing to participate would be transferred to a customer service representative for the program and would either select the electric supplier from which they would like to take service or be placed with a participating electric supplier chosen at random on a rotating basis.

Nothing in this Section shall prevent the Office of Retail Market Development or the Commission from considering retail choice and referral programs in addition to the programs outlined in this Section.

(Source: P.A. 95-700, eff. 11-9-07.)

(220 ILCS 5/Art. XXI heading) ARTICLE XXI. CABLE AND VIDEO COMPETITION (Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-100)

Sec. 21-100. Short title. This Article may be cited as the Cable and Video Competition Law of 2007.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-101)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-101. Findings. With respect to cable and video competition, the General Assembly finds that:

(a) The economy in the State of Illinois will be enhanced by investment in new communications, cable services, and video services infrastructure, including broadband facilities, fiber optic, and Internet protocol technologies.

(b) Cable services and video services bring important daily benefits to Illinois consumers by providing news, education, and entertainment.

(c) Competitive cable service and video service providers are capable of providing new video programming services and competition to Illinois consumers and of decreasing the prices for video programming services paid by Illinois consumers.

(d) Although there has been some competitive entry into the facilities-based video programming market since current franchising requirements in this State were enacted, further entry by facilities-based providers could benefit consumers, provided cable and video services are equitably available to all Illinois consumers at reasonable prices.

(e) The provision of competitive cable services and video services is a matter of statewide concern that extends beyond the boundaries of individual local units of government. Notwithstanding the foregoing, public rights-of-way are limited resources over which the municipality has a custodial duty to ensure that they are used, repaired, and maintained in a manner that best serves the public interest.

(f) The State authorization process and uniform standards and procedures in this Article are intended to enable rapid and widespread entry by competitive providers, which will bring to Illinois consumers the benefits of video competition, including providing consumers with more choice, lower prices, higher speed and more advanced Internet access, more diverse and varied news, public information, education, and entertainment programming, and will bring to this State and its local units of government the benefits of new infrastructure investment, job growth, and innovation in broadband and Internet protocol technologies and deployment.

(g) Providing an incumbent cable or video service provider with the option to secure a State-issued authorization through the termination of existing cable franchises between incumbent cable and video service providers and any local franchising authority is part of the new regulatory framework established by this Article. This Article is intended to best ensure equal treatment and parity among providers and technologies.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-101.1)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-101.1. Applicability. The provisions of Public Act 95-9 shall apply only to a holder of a cable service or video service authorization issued by the Commission pursuant to this Article, and shall not apply to any person or entity that provides cable television services under a cable television franchise issued by any municipality or county pursuant to Section 11-42-11 of the Illinois Municipal Code (65 ILCS 5/11-42-11) or Section 5-1095 of the Counties Code (55 ILCS 5/5-1095), unless specifically provided for herein. A local unit of government that has an existing agreement for the provision of video services with a company or entity that uses its telecommunications facilities to provide video service as of May 30, 2007 may continue to operate under that agreement or may, at its discretion, terminate the existing agreement and require the video provider to obtain a State-issued authorization under this Article.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-201)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-201. Definitions. As used in this Article:

(a) "Access" means that the cable or video provider is capable of providing cable services or video services at the household address using any technology, other than direct-to-home satellite service, that provides 2-way broadband Internet capability and video programming, content, and functionality, regardless of whether any customer has ordered service or whether the owner or landlord or other responsible person has granted access to the household. If more than one technology is used, the technologies shall provide similar 2-way broadband Internet accessibility and similar video programming.

(b) "Basic cable or video service" means any cable or video service offering or tier that includes the retransmission of local television broadcast signals.

(c) "Broadband service" means a high speed service connection to the public Internet capable of supporting, in at least one direction, a speed in excess of 200 kilobits per second (kbps) to the network demarcation point at the subscriber's premises.

(d) "Cable operator" means that term as defined in item (5) of 47 U.S.C. 522.

(e) "Cable service" means that term as defined in item (6) of 47 U.S.C. 522.

(f) "Cable system" means that term as defined in item (7) of 47 U.S.C. 522.

(g) "Commission" means the Illinois Commerce Commission.

(h) "Competitive cable service or video service provider" means a person or entity that is providing or seeks to provide cable service or video service in an area where there is at least one incumbent cable operator.

(i) "Designated market area" means a designated market area, as determined by Nielsen Media Research and published in the 1999-2000 Nielsen Station Index Directory and Nielsen Station Index United States Television Household Estimates or any successor publication. For any designated market area that crosses State lines, only households in the portion of the designated market area that is located within the holder's telecommunications service area in the State where access to video service will be offered shall be considered.

(j) "Footprint" means the geographic area designated by the cable service or video service provider as the geographic area in which it will offer cable services or video services during the period of its State-issued authorization. Each footprint shall be identified in terms of either (i) exchanges, as that term is defined in Section 13-206 of this Act; (ii) a collection of United States Census Bureau Block numbers (13 digit); (iii) if the area is smaller than the areas identified in either (i) or (ii), by geographic information system digital boundaries meeting or exceeding national map accuracy standards; or (iv) local units of government.

(k) "Holder" means a person or entity that has received authorization to offer or provide cable or video service from the Commission pursuant to Section 21-401 of this Article.

(l) "Household" means a house, an apartment, a mobile home, a group of rooms, or a single room that is intended for occupancy as separate living quarters. Separate living quarters are those in which the occupants live and eat separately from any other persons in the building and that have direct access from the outside of the building or through a common hall. This definition is consistent with the United States Census Bureau, as that definition may be amended thereafter.

(m) "Incumbent cable operator" means a person or entity that provided cable services or video services in a particular area under a franchise agreement with a local unit of government pursuant to Section 11-42-11 of the Illinois Municipal Code (65 ILCS 5/11-42-11) or Section 5-1095 of the Counties Code (55 ILCS 5/5-1095) on January 1, 2007.

(n) "Local franchising authority" means the local unit of government that has or requires a franchise with a cable operator, a provider of cable services, or a provider of video services to construct or operate a cable or video system or to offer cable services or video services under Section 11-42-11 of the Illinois Municipal Code (65 ILCS 5/11-42-11) or Section 5-1095 of the Counties Code (55 ILCS 5/5-1095).

(o) "Local unit of government" means a city, village, incorporated town, or county.

(p) "Low-income household" means those residential households located within the holder's existing telephone service area where the average annual household income is less than $35,000, based on the United States Census Bureau estimates adjusted annually to reflect rates of change and distribution.

(q) "Public rights-of-way" means the areas on, below, or above a public roadway, highway, street, public sidewalk, alley, waterway, or utility easements dedicated for compatible uses.

(r) "Service" means the provision of cable service or video service to subscribers and the interaction of subscribers with the person or entity that has received authorization to offer or provide cable or video service from the Commission pursuant to Section 21-401 of this Act.

(s) "Service provider fee" means the amount paid under Section 21-801 of this Act by the holder to a municipality, or in the case of an unincorporated service area to a county, for service areas within its territorial jurisdiction, but under no circumstances shall the service provider fee be paid to more than one local unit of government for the same portion of the holder's service area.

(t) "Telecommunications service area" means the area designated by the Commission as the area in which a telecommunications company was obligated to provide non-competitive local telephone service as of February 8, 1996 as incorporated into Section 13-202.5 of this Act.

(u) "Video programming" means that term as defined in item (20) of 47 U.S.C. 522.

(v) "Video service" means video programming provided by a video service provider and subscriber interaction, if any, that is required for the selection or use of such video programming services, and that is provided through wireline facilities located at least in part in the public rights-of-way without regard to delivery technology, including Internet protocol technology. This definition does not include the following: (1) any video programming provided by a commercial mobile service provider defined in subsection (d) of 47 U.S.C. 332; (2) direct-to-home satellite services defined in subsection (v) of 47 U.S.C. 303; or (3) any video programming accessed via a service that enables users to access content, information, electronic mail, or other services offered over the Internet, including Internet streaming content.

(Source: P.A. 103-360, eff. 1-1-24.)

(220 ILCS 5/21-301)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-301. Eligibility.

(a) A person or entity seeking to provide cable service or video service in this State after June 30, 2007 (the effective date of Public Act 95-9) shall either (1) obtain a State-issued authorization pursuant to Section 21-401 of the Public Utilities Act (220 ILCS 5/21-401); (2) obtain authorization pursuant to Section 11-42-11 of the Illinois Municipal Code (65 ILCS 5/11-42-11); or (3) obtain authorization pursuant to Section 5-1095 of the Counties Code (55 ILCS 5/5-1095).

(b) An incumbent cable operator shall be eligible to apply for a State-issued authorization as provided in subsection (c) of this Section. Upon expiration of its current franchise agreement, an incumbent cable operator may obtain State authorization from the Commission pursuant to this Article or may pursue a franchise renewal with the appropriate local franchise authority under State and federal law. An incumbent cable operator and any successor-in-interest that receives a State-issued authorization shall be obligated to provide access to cable services or video services within any local unit of government at the same levels required by the local franchising authorities for the local unit of government on June 30, 2007 (the effective date of Public Act 95-9).

(c)(1) An incumbent cable operator may elect to terminate its agreement with the local franchising authority and obtain a State-issued authorization by providing written notice to the Commission and the affected local franchising authority and any entity authorized by that franchising authority to manage public, education, and government access at least 180 days prior to its filing an application for a State-issued authorization. The existing agreement shall be terminated on the date that the Commission issues the State-issued authorization.

(2) An incumbent cable operator that elects to terminate an existing agreement with a local franchising authority under this Section is responsible for remitting to the affected local franchising authority and any entity designated by that local franchising authority to manage public, education, and government access before the 46th day after the date the agreement is terminated any accrued but unpaid fees due under the terminated agreement. If that incumbent cable operator has credit remaining from prepaid franchise fees, such amount of the remaining credit may be deducted from any future fees the incumbent cable operator must pay to the local franchising authority pursuant to subsection (b) of Section 21-801 of this Act.

(3) An incumbent cable operator that elects to terminate an existing agreement with a local franchising authority under this Section shall pay the affected local franchising authority and any entity designated by that franchising authority to manage public, education, and government access, at the time that they would have been due, all monetary payments for public, education, or government access that would have been due during the remaining term of the agreement had it not been terminated as provided in this paragraph. All payments made by an incumbent cable operator pursuant to the previous sentence of this paragraph may be credited against the fees that that operator owes under item (1) of subsection (d) of Section 21-801 of this Act.

(d) For purposes of this Article, the Commission shall be the franchising authority for cable service or video service providers that apply for and obtain a State-issued authorization under this Article with regard to the footprint covered by such authorization. Notwithstanding any other provision of this Article, holders using telecommunications facilities to provide cable service or video service are not obligated to provide that service outside the holder's telecommunications service area.

(e) Any person or entity that applies for and obtains a State-issued authorization under this Article shall not be subject to Section 11-42-11 of the Illinois Municipal Code (65 ILCS 5/11-42-11) or Section 5-1095 of the Counties Code (55 ILCS 5/5-1095), except as provided in this Article. Except as provided under this Article, neither the Commission nor any local unit of government may require a person or entity that has applied for and obtained a State-issued authorization to obtain a separate franchise or pay any franchise fee on cable service or video service.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-401)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-401. Applications.

(a)(1) A person or entity seeking to provide cable service or video service pursuant to this Article shall not use the public rights-of-way for the installation or construction of facilities for the provision of cable service or video service or offer cable service or video service until it has obtained a State-issued authorization to offer or provide cable or video service under this Section, except as provided for in item (2) of this subsection (a). All cable or video providers offering or providing service in this State shall have authorization pursuant to either (i) the Cable and Video Competition Law of 2007 (220 ILCS 5/21-100 et seq.); (ii) Section 11-42-11 of the Illinois Municipal Code (65 ILCS 5/11-42-11); or (iii) Section 5-1095 of the Counties Code (55 ILCS 5/5-1095).

(2) Nothing in this Section shall prohibit a local unit of government from granting a permit to a person or entity for the use of the public rights-of-way to install or construct facilities to provide cable service or video service, at its sole discretion. No unit of local government shall be liable for denial or delay of a permit prior to the issuance of a State-issued authorization.

(b) The application to the Commission for State-issued authorization shall contain a completed affidavit submitted by the applicant and signed by an officer or general partner of the applicant affirming all of the following:

(1) That the applicant has filed or will timely file with the Federal Communications Commission all forms required by that agency in advance of offering cable service or video service in this State.

(2) That the applicant agrees to comply with all applicable federal and State statutes and regulations.

(3) That the applicant agrees to comply with all applicable local unit of government regulations.

(4) An exact description of the cable service or video service area where the cable service or video service will be offered during the term of the State-issued authorization. The service area shall be identified in terms of either (i) exchanges, as that term is defined in Section 13-206 of this Act; (ii) a collection of United States Census Bureau Block numbers (13 digit); (iii) if the area is smaller than the areas identified in either (i) or (ii), by geographic information system digital boundaries meeting or exceeding national map accuracy standards; or (iv) local unit of government. The description shall include the number of low-income households within the service area or footprint. If an applicant is an incumbent cable operator, the incumbent cable operator and any successor-in-interest shall be obligated to provide access to cable services or video services within any local units of government at the same levels required by the local franchising authorities for the local unit of government on June 30, 2007 (the effective date of Public Act 95-9), and its application shall provide a description of an area no smaller than the service areas contained in its franchise or franchises within the jurisdiction of the local unit of government in which it seeks to offer cable or video service.

(5) The location and telephone number of the applicant's principal place of business within this State and the names of the applicant's principal executive officers who are responsible for communications concerning the application and the services to be offered pursuant to the application, the applicant's legal name, and any name or names under which the applicant does or will provide cable services or video services in this State.

(6) A certification that the applicant has concurrently delivered a copy of the application to all local units of government that include all or any part of the service area identified in item (4) of this subsection (b) within such local unit of government's jurisdictional boundaries.

(7) The expected date that cable service or video service will be initially offered in the area identified in item (4) of this subsection (b). In the event that a holder does not offer cable services or video services within 3 months after the expected date, it shall amend its application and update the expected date service will be offered and explain the delay in offering cable services or video services.

(8) For any entity that received State-issued authorization prior to this amendatory Act of the 98th General Assembly as a cable operator and that intends to proceed as a cable operator under this Article, the entity shall file a written affidavit with the Commission and shall serve a copy of the affidavit with any local units of government affected by the authorization within 30 days after the effective date of this amendatory Act of the 98th General Assembly stating that the holder will be providing cable service under the State-issued authorization.

The application shall include adequate assurance that the applicant possesses the financial, managerial, legal, and technical qualifications necessary to construct and operate the proposed system, to promptly repair any damage to the public right-of-way caused by the applicant, and to pay the cost of removal of its facilities. To accomplish these requirements, the applicant may, at the time the applicant seeks to use the public rights-of-way in that jurisdiction, be required by the State of Illinois or later be required by the local unit of government, or both, to post a bond, produce a certificate of insurance, or otherwise demonstrate its financial responsibility.

The application shall include the applicant's general standards related to customer service required by Section 22-501 of this Act, which shall include, but not be limited to, installation, disconnection, service and repair obligations; appointment hours; employee ID requirements; customer service telephone numbers and hours; procedures for billing, charges, deposits, refunds, and credits; procedures for termination of service; notice of deletion of programming service and changes related to transmission of programming or changes or increases in rates; use and availability of parental control or lock-out devices; complaint procedures and procedures for bill dispute resolution and a description of the rights and remedies available to consumers if the holder does not materially meet their customer service standards; and special services for customers with visual, hearing, or mobility disabilities.

(c)(1) The applicant may designate information that it submits in its application or subsequent reports as confidential or proprietary, provided that the applicant states the reasons the confidential designation is necessary. The Commission shall provide adequate protection for such information pursuant to Section 4-404 of this Act. If the Commission, a local unit of government, or any other party seeks public disclosure of information designated as confidential, the Commission shall consider the confidential designation in a proceeding under the Illinois Administrative Procedure Act, and the burden of proof to demonstrate that the designated information is confidential shall be upon the applicant. Designated information shall remain confidential pending the Commission's determination of whether the information is entitled to confidential treatment. Information designated as confidential shall be provided to local units of government for purposes of assessing compliance with this Article as permitted under a Protective Order issued by the Commission pursuant to the Commission's rules and to the Attorney General pursuant to Section 6.5 of the Attorney General Act (15 ILCS 205/6.5). Information designated as confidential under this Section or determined to be confidential upon Commission review shall only be disclosed pursuant to a valid and enforceable subpoena or court order or as required by the Freedom of Information Act. Nothing herein shall delay the application approval timeframes set forth in this Article.

(2) Information regarding the location of video services that have been or are being offered to the public and aggregate information included in the reports required by this Article shall not be designated or treated as confidential.

(d)(1) The Commission shall post all applications it receives under this Article on its web site within 5 business days.

(2) The Commission shall notify an applicant for a cable service or video service authorization whether the applicant's application and affidavit are complete on or before the 15th business day after the applicant submits the application. If the application and affidavit are not complete, the Commission shall state in its notice all of the reasons the application or affidavit are incomplete, and the applicant shall resubmit a complete application. The Commission shall have 30 days after submission by the applicant of a complete application and affidavit to issue the service authorization. If the Commission does not notify the applicant regarding the completeness of the application and affidavit or issue the service authorization within the time periods required under this subsection, the application and affidavit shall be considered complete and the service authorization issued upon the expiration of the 30th day.

(e) Any authorization issued by the Commission will expire on December 31, 2029 and shall contain or include all of the following:

(1) A grant of authority, including an authorization issued prior to this amendatory Act of the 98th General Assembly, to provide cable service or video service in the service area footprint as requested in the application, subject to the provisions of this Article in existence on the date the grant of authority was issued, and any modifications to this Article enacted at any time prior to the date in Section 21-1601 of this Act, and to the laws of the State and the ordinances, rules, and regulations of the local units of government.

(2) A grant of authority to use, occupy, and construct facilities in the public rights-of-way for the delivery of cable service or video service in the service area footprint, subject to the laws, ordinances, rules, or regulations of this State and local units of governments.

(3) A statement that the grant of authority is subject to lawful operation of the cable service or video service by the applicant, its affiliated entities, or its successors-in-interest.

(e-5) The Commission shall notify a local unit of government within 3 business days of the grant of any authorization within a service area footprint if that authorization includes any part of the local unit of government's jurisdictional boundaries and state whether the holder will be providing video service or cable service under the authorization.

(f) The authorization issued pursuant to this Section by the Commission may be transferred to any successor-in-interest to the applicant to which it is initially granted without further Commission action if the successor-in-interest (i) submits an application and the information required by subsection (b) of this Section for the successor-in-interest and (ii) is not in violation of this Article or of any federal, State, or local law, ordinance, rule, or regulation. A successor-in-interest shall file its application and notice of transfer with the Commission and the relevant local units of government no less than 15 business days prior to the completion of the transfer. The Commission is not required or authorized to act upon the notice of transfer; however, the transfer is not effective until the Commission approves the successor-in-interest's application. A local unit of government or the Attorney General may seek to bar a transfer of ownership by filing suit in a court of competent jurisdiction predicated on the existence of a material and continuing breach of this Article by the holder, a pattern of noncompliance with customer service standards by the potential successor-in-interest, or the insolvency of the potential successor-in-interest. If a transfer is made when there are violations of this Article or of any federal, State, or local law, ordinance, rule, or regulation, the successor-in-interest shall be subject to 3 times the penalties provided for in this Article.

(g) The authorization issued pursuant to this Section by the Commission may be terminated, or its cable service or video service area footprint may be modified, by the cable service provider or video service provider by submitting notice to the Commission and to the relevant local unit of government containing a description of the change on the same terms as the initial description pursuant to item (4) of subsection (b) of this Section. The Commission is not required or authorized to act upon that notice. It shall be a violation of this Article for a holder to discriminate against potential residential subscribers because of the race or income of the residents in the local area in which the group resides by terminating or modifying its cable service or video service area footprint. It shall be a violation of this Article for a holder to terminate or modify its cable service or video service area footprint if it leaves an area with no cable service or video service from any provider.

(h) The Commission's authority to administer this Article is limited to the powers and duties explicitly provided under this Article. Its authority under this Article does not include or limit the powers and duties that the Commission has under the other Articles of this Act, the Illinois Administrative Procedure Act, or any other law or regulation to conduct proceedings, other than as provided in subsection (c), or has to promulgate rules or regulations. The Commission shall not have the authority to limit or expand the obligations and requirements provided in this Section or to regulate or control a person or entity to the extent that person or entity is providing cable service or video service, except as provided in this Article.

(Source: P.A. 101-639, eff. 6-12-20; 102-9, eff. 6-3-21.)

(220 ILCS 5/21-601)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-601. Public, education, and government access. For the purposes of this Section, "programming" means content produced or provided by any person, group, governmental agency, or noncommercial public or private agency or organization.

(a) Not later than 90 days after a request by the local unit of government or its designee that has received notice under subsection (a) of Section 21-801 of this Act, the holder shall (i) designate the same amount of capacity on its network to provide for public, education, and government access use as the incumbent cable operator is required to designate under its franchise terms in effect with a local unit of government on January 1, 2007 and (ii) retransmit to its subscribers the same number of public, education, and government access channels as the incumbent cable operator was retransmitting to subscribers on January 1, 2007.

(b) If the local unit of government produces or maintains the public education or government programming in a manner or form that is compatible with the holder's network, it shall transmit such programming to the holder in that form provided that form permits the holder to satisfy the requirements of subsection (c) of this Section. If the local unit of government does not produce or maintain such programming in that manner or form, then the holder shall be responsible for any changes in the form of the transmission necessary to make public, education, and government programming compatible with the technology or protocol used by the holder to deliver services. The holder shall receive programming from the local unit of government (or the local unit of government's public, education, and government programming providers) and transmit that public, education, and government programming directly to the holder's subscribers within the local unit of government's jurisdiction at no cost to the local unit of government or the public, education, and government programming providers. If the holder is required to change the form of the transmission, the local unit of government or its designee shall provide reasonable access to the holder to allow the holder to transmit the public, education, and government programming in an economical manner subject to the requirements of subsection (c) of this Section.

(c) The holder shall provide to subscribers public, education, and government access channel capacity at equivalent visual and audio quality and equivalent functionality, from the viewing perspective of the subscriber, to that of commercial channels carried on the holder's basic cable or video service offerings or tiers without the need for any equipment other than the equipment necessary to receive the holder's basic cable or video service offerings or tiers.

(d) The holder and an incumbent cable operator shall negotiate in good faith to interconnect their networks, if needed, for the purpose of providing public, education, and government programming. Interconnection may be accomplished by direct cable, microwave link, satellite, or other reasonable method of connection. The holder and the incumbent cable operator shall provide interconnection of the public, education, and government channels on reasonable terms and conditions and may not withhold the interconnection. If a holder and an incumbent cable operator cannot reach a mutually acceptable interconnection agreement, the local unit of government may require the incumbent cable operator to allow the holder to interconnect its network with the incumbent cable operator's network at a technically feasible point on their networks. If no technically feasible point for interconnection is available, the holder and an incumbent cable operator shall each make an interconnection available to the public, education, and government channel originators at their local origination points and shall provide the facilities necessary for the interconnection. The cost of any interconnection shall be borne by the holder unless otherwise agreed to by the parties. The interconnection required by this subsection shall be completed within the 90-day deadline set forth in subsection (a) of this Section.

(e) The public, education, and government channels shall be for the exclusive use of the local unit of government or its designee to provide public, education, and government programming. The public, education, and government channels shall be used only for noncommercial purposes. However, advertising, underwriting, or sponsorship recognition may be carried on the channels for the purpose of funding public, education, and government access related activities.

(f) Public, education, and government channels shall all be carried on the holder's basic cable or video service offerings or tiers. To the extent feasible, the public, education, and government channels shall not be separated numerically from other channels carried on the holder's basic cable or video service offerings or tiers, and the channel numbers for the public, education, and government channels shall be the same channel numbers used by the incumbent cable operator, unless prohibited by federal law. After the initial designation of public, education, and government channel numbers, the channel numbers shall not be changed without the agreement of the local unit of government or the entity to which the local unit of government has assigned responsibility for managing public, education, and government access channels, unless the change is required by federal law. Each channel shall be capable of carrying a National Television System Committee (NTSC) television signal.

(g) The holder shall provide a listing of public, education, and government channels on channel cards and menus provided to subscribers in a manner equivalent to other channels if the holder uses such cards and menus. Further, the holder shall provide a listing of public, education, and government programming on its electronic program guide if such a guide is utilized by the holder. It is the public, education, and government entity's responsibility to provide the holder or its designated agent, as determined by the holder, with program schedules and information in a timely manner.

(h) If less than 3 public, education, and government channels are provided within the local unit of government as of January 1, 2007, a local unit of government whose jurisdiction lies within the authorized service area of the holder may initially request the holder to designate sufficient capacity for up to 3 public, education, and government channels. A local unit of government or its designee that seeks to add additional capacity shall give the holder a written notification specifying the number of additional channels to be used, specifying the number of channels in actual use, and verifying that the additional channels requested will be put into actual use.

(i) The holder shall, within 90 days of a request by the local unit of government or its designated public, education, or government access entity, provide sufficient capacity for an additional channel for public, education, and government access when the programming on a given access channel exceeds 40 hours per week as measured on a quarterly basis. The additional channel shall not be used for any purpose other than for carrying additional public, education, or government access programming.

(j) The public, education, and government access programmer is solely responsible for the content that it provides over designated public, education, or government channels. A holder shall not exercise any editorial control over any programming on any channel designed for public, education, or government use or on any other channel required by law or a binding agreement with the local unit of government.

(k) A holder shall not be subject to any civil or criminal liability for any program carried on any channel designated for public, education, or government use.

(l) A court of competent jurisdiction shall have exclusive jurisdiction to enforce any requirement under this Section or resolve any dispute regarding the requirements set forth in this Section, and no provider of cable service or video service may be barred from providing service or be required to terminate service as a result of that dispute or enforcement action.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-701)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-701. Emergency alert system. The holder shall comply with all applicable requirements of the Federal Communications Commission involving the distribution and notification of federal, State, and local emergency messages over the emergency alert system applicable to cable operators. The holder will provide a requesting local unit of government with sufficient information regarding how to submit, via telephone or web listing, a local emergency alert for distribution over its cable or video network. To the extent that a local unit of government requires incumbent cable operators to provide emergency alert system messages or services in excess of the requirements of this Section, the holder shall comply with any such additional requirements within the jurisdiction of the local franchising authority. The holder may provide a local emergency alert to an area larger than the boundaries of the local unit of government issuing the emergency alert.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-801)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-801. Applicable fees payable to the local unit of government.

(a) Prior to offering cable service or video service in a local unit of government's jurisdiction, a holder shall notify the local unit of government. The notice shall be given to the local unit of government at least 10 days before the holder begins to offer cable service or video service within the boundaries of that local unit of government.

(b) In any local unit of government in which a holder offers cable service or video service on a commercial basis, the holder shall be liable for and pay the service provider fee to the local unit of government. The local unit of government shall adopt an ordinance imposing such a fee. The holder's liability for the fee shall commence on the first day of the calendar month that is at least 30 days after the holder receives such ordinance. For any such ordinance adopted on or after the effective date of this amendatory Act of the 99th General Assembly, the holder's liability shall commence on the first day of the calendar month that is at least 30 days after the adoption of such ordinance. The ordinance shall be sent by mail, postage prepaid, to the address listed on the holder's application provided to the local unit of government pursuant to item (6) of subsection (b) of Section 21-401 of this Act. The fee authorized by this Section shall be 5% of gross revenues or the same as the fee paid to the local unit of government by any incumbent cable operator providing cable service. The payment of the service provider fee shall be due on a quarterly basis, 45 days after the close of the calendar quarter. If mailed, the fee is considered paid on the date it is postmarked. Except as provided in this Article, the local unit of government may not demand any additional fees or charges from the holder and may not demand the use of any other calculation method other than allowed under this Article.

(c) For purposes of this Article, "gross revenues" means all consideration of any kind or nature, including, without limitation, cash, credits, property, and in-kind contributions received by the holder for the operation of a cable or video system to provide cable service or video service within the holder's cable service or video service area within the local unit of government's jurisdiction.

(1) Gross revenues shall include the following:

(i) Recurring charges for cable service or video service.

(ii) Event-based charges for cable service or video service, including, but not limited to, pay-per-view and video-on-demand charges.

(iii) Rental of set-top boxes and other cable service or video service equipment.

(iv) Service charges related to the provision of cable service or video service, including, but not limited to, activation, installation, and repair charges.

(v) Administrative charges related to the provision of cable service or video service, including but not limited to service order and service termination charges.

(vi) Late payment fees or charges, insufficient funds check charges, and other charges assessed to recover the costs of collecting delinquent payments.

(vii) A pro rata portion of all revenue derived by the holder or its affiliates pursuant to compensation arrangements for advertising or for promotion or exhibition of any products or services derived from the operation of the holder's network to provide cable service or video service within the local unit of government's jurisdiction. The allocation shall be based on the number of subscribers in the local unit of government divided by the total number of subscribers in relation to the relevant regional or national compensation arrangement.

(viii) Compensation received by the holder that is derived from the operation of the holder's network to provide cable service or video service with respect to commissions that are received by the holder as compensation for promotion or exhibition of any products or services on the holder's network, such as a "home shopping" or similar channel, subject to item (ix) of this paragraph (1).

(ix) In the case of a cable service or video service that is bundled or integrated functionally with other services, capabilities, or applications, the portion of the holder's revenue attributable to the other services, capabilities, or applications shall be included in gross revenue unless the holder can reasonably identify the division or exclusion of the revenue from its books and records that are kept in the regular course of business.

(x) The service provider fee permitted by subsection (b) of this Section.

(2) Gross revenues do not include any of the following:

(i) Revenues not actually received, even if billed, such as bad debt, subject to item (vi) of paragraph (1) of this subsection (c).

(ii) Refunds, discounts, or other price adjustments that reduce the amount of gross revenues received by the holder of the State-issued authorization to the extent the refund, rebate, credit, or discount is attributable to cable service or video service.

(iii) Regardless of whether the services are bundled, packaged, or functionally integrated with cable service or video service, any revenues received from services not classified as cable service or video service, including, without limitation, revenue received from telecommunications services, information services, or the provision of directory or Internet advertising, including yellow pages, white pages, banner advertisement, and electronic publishing, or any other revenues attributed by the holder to noncable service or nonvideo service in accordance with the holder's books and records and records kept in the regular course of business and any applicable laws, rules, regulations, standards, or orders.

(iv) The sale of cable services or video services for resale in which the purchaser is required to collect the service provider fee from the purchaser's subscribers to the extent the purchaser certifies in writing that it will resell the service within the local unit of government's jurisdiction and pay the fee permitted by subsection (b) of this Section with respect to the service.

(v) Any tax or fee of general applicability imposed upon the subscribers or the transaction by a city, State, federal, or any other governmental entity and collected by the holder of the State-issued authorization and required to be remitted to the taxing entity, including sales and use taxes.

(vi) Security deposits collected from subscribers.

(vii) Amounts paid by subscribers to "home shopping" or similar vendors for merchandise sold through any home shopping channel offered as part of the cable service or video service.

(viii) Any revenues received from video programming accessed via a service that enables users to access content, information, electronic mail, or other services offered over the Internet, including Internet streaming content.

(3) Revenue of an affiliate of a holder shall be included in the calculation of gross revenues to the extent the treatment of the revenue as revenue of the affiliate rather than the holder has the effect of evading the payment of the fee permitted by subsection (b) of this Section which would otherwise be paid by the cable service or video service.

(d)(1) Except for a holder providing cable service that is subject to the fee in subsection (i) of this Section, the holder shall pay to the local unit of government or the entity designated by that local unit of government to manage public, education, and government access, upon request as support for public, education, and government access, a fee equal to no less than (i) 1% of gross revenues or (ii) if greater, the percentage of gross revenues that incumbent cable operators pay to the local unit of government or its designee for public, education, and government access support in the local unit of government's jurisdiction. For purposes of item (ii) of paragraph (1) of this subsection (d), the percentage of gross revenues that all incumbent cable operators pay shall be equal to the annual sum of the payments that incumbent cable operators in the service area are obligated to pay by franchises and agreements or by contracts with the local government designee for public, education and government access in effect on January 1, 2007, including the total of any lump sum payments required to be made over the term of each franchise or agreement divided by the number of years of the applicable term, divided by the annual sum of such incumbent cable operator's or operators' gross revenues during the immediately prior calendar year. The sum of payments includes any payments that an incumbent cable operator is required to pay pursuant to item (3) of subsection (c) of Section 21-301.

(2) A local unit of government may require all holders of a State-issued authorization and all cable operators franchised by that local unit of government on June 30, 2007 (the effective date of this Section) in the franchise area to provide to the local unit of government, or to the entity designated by that local unit of government to manage public, education, and government access, information sufficient to calculate the public, education, and government access equivalent fee and any credits under paragraph (1) of this subsection (d).

(3) The fee shall be due on a quarterly basis and paid 45 days after the close of the calendar quarter. Each payment shall include a statement explaining the basis for the calculation of the fee. If mailed, the fee is considered paid on the date it is postmarked. The liability of the holder for payment of the fee under this subsection shall commence on the same date as the payment of the service provider fee pursuant to subsection (b) of this Section.

(e) The holder may identify and collect the amount of the service provider fee as a separate line item on the regular bill of each subscriber.

(f) The holder may identify and collect the amount of the public, education, and government programming support fee as a separate line item on the regular bill of each subscriber.

(g) All determinations and computations under this Section shall be made pursuant to the definition of gross revenues set forth in this Section and shall be made pursuant to generally accepted accounting principles.

(h) Nothing contained in this Article shall be construed to exempt a holder from any tax that is or may later be imposed by the local unit of government, including any tax that is or may later be required to be paid by or through the holder with respect to cable service or video service. A State-issued authorization shall not affect any requirement of the holder with respect to payment of the local unit of government's simplified municipal telecommunications tax or any other tax as it applies to any telephone service provided by the holder. A State-issued authorization shall not affect any requirement of the holder with respect to payment of the local unit of government's 911 or E911 fees, taxes, or charges.

(i) Except for a municipality having a population of 2,000,000 or more, the fee imposed under paragraph (1) of subsection (d) by a local unit of government against a holder who is a cable operator shall be as follows:

(1) the fee shall be collected and paid only for capital costs that are considered lawful under Subchapter VI of the federal Communications Act of 1934, as amended, and as implemented by the Federal Communications Commission;

(2) the local unit of government shall impose any fee by ordinance; and

(3) the fee may not exceed 1% of gross revenue; if, however, on the date that an incumbent cable operator files an application under Section 21-401, the incumbent cable operator is operating under a franchise agreement that imposes a fee for support for capital costs for public, education, and government access facilities obligations in excess of 1% of gross revenue, then the cable operator shall continue to provide support for capital costs for public, education, and government access facilities obligations at the rate stated in such agreement.

(Source: P.A. 103-360, eff. 1-1-24.)

(220 ILCS 5/21-901)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-901. Audits.

(a) A holder that has received State-issued authorization under this Article is subject to an audit of its service provider fees derived from the provision of cable or video services to subscribers within any part of the local unit of government which is located in the holder's service territory. Any such audit shall be conducted by the local unit of government or its agent for the sole purpose of determining any overpayment or underpayment of the holder's service provider fee to the local unit of government.

(b) Beginning on or after the effective date of this amendatory Act of the 99th General Assembly, any audit conducted pursuant to this Section by a local government shall be governed by Section 11-42-11.05 of the Illinois Municipal Code or Section 5-1095.1 of the Counties Code.

(Source: P.A. 99-6, eff. 6-29-15; 100-20, eff. 7-1-17.)

(220 ILCS 5/21-1001)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-1001. Local unit of government authority.

(a) The holder of a State-issued authorization shall comply with all the applicable construction and technical standards and right-of-way occupancy standards set forth in a local unit of government's code of ordinances relating to the use of public rights-of-way, pole attachments, permit obligations, indemnification, performance bonds, penalties, or liquidated damages. The applicable requirements for a holder that is using its existing telecommunications network or constructing a telecommunications network shall be the same requirements that the local unit of government imposes on telecommunications providers in its jurisdiction. The applicable requirements for a holder that is using or constructing a cable system shall be the same requirements the local unit of government imposes on other cable operators in its jurisdiction.

(b) A local unit of government shall allow the holder to install, construct, operate, maintain, and remove a cable service, video service, or telecommunications network within a public right-of-way and shall provide the holder with open, comparable, nondiscriminatory, and competitively neutral access to the public right-of-way on the same terms applicable to other cable service or video service providers or cable operators in its jurisdiction. Notwithstanding any other provisions of law, if a local unit of government is permitted by law to require the holder of a State authorization to seek a permit to install, construct, operate, maintain, or remove its cable service, video service, or telecommunications network within a public right-of-way, those permits shall be deemed granted within 45 days after being submitted, if not otherwise acted upon by the local unit of government, provided the holder complies with the requirements applicable to the holder in its jurisdiction.

(c) A local unit of government may impose reasonable terms, but it may not discriminate against the holder with respect to any of the following:

(1) The authorization or placement of a cable service, video service, or telecommunications network or equipment in public rights-of-way.

(2) Access to a building.

(3) A local unit of government utility pole attachment.

(d) If a local unit of government imposes a permit fee on incumbent cable operators, it may impose a permit fee on the holder only to the extent it imposes such a fee on incumbent cable operators. In all other cases, these fees may not exceed the actual, direct costs incurred by the local unit of government for issuing the relevant permit. In no event may a fee under this Section be levied if the holder already has paid a permit fee of any kind in connection with the same activity that would otherwise be covered by the permit fee under this Section provided no additional equipment, work, function, or other burden is added to the existing activity for which the permit was issued.

(e) Nothing in this Article shall affect the rights that any holder has under Section 4 of the Telephone Line Right of Way Act (220 ILCS 65/4).

(f) In addition to the other requirements in this Section, if the holder installs, upgrades, constructs, operates, maintains, and removes facilities or equipment within a public right-of-way to provide cable service or video service, it shall comply with the following:

(1) The holder must locate its equipment in the right-of-way as to cause only minimum interference with the use of streets, alleys, and other public ways and places, and to cause only minimum impact upon and interference with the rights and reasonable convenience of property owners who adjoin any of the said streets, alleys, or other public ways. No fixtures shall be placed in any public ways in such a manner to interfere with the usual travel on such public ways, nor shall such fixtures or equipment limit the visibility of vehicular or pedestrian traffic, or both.

(2) The holder shall comply with a local unit of government's reasonable requests to place equipment on public property where possible and promptly comply with local unit of government direction with respect to the location and screening of equipment and facilities. In constructing or upgrading its cable or video network in the right-of-way, the holder shall use the smallest suitable equipment enclosures and power pedestals and cabinets then in use by the holder for the application.

(3) The holder's construction practices shall be in accordance with all applicable Sections of the Occupational Safety and Health Act of 1970, as amended, as well as all applicable State laws, including the Civil Administrative Code of Illinois, and local codes, where applicable, as adopted by the local unit of government. All installation of electronic equipment shall be of a permanent nature, durable, and, where applicable, installed in accordance with the provisions of the National Electrical Safety Code of the National Bureau of Standards and National Electrical Code of the National Board of Fire Underwriters.

(4) The holder shall not interfere with the local unit of government's performance of public works. Nothing in the State-issued authorization shall be in preference or hindrance to the right of the local unit of government to perform or carry on any public works or public improvements of any kind. The holder expressly agrees that it shall, at its own expense, protect, support, temporarily disconnect, relocate in the same street or other public place, or remove from such street or other public place any of the network, system, facilities, or equipment when required to do so by the local unit of government because of necessary public health, safety, and welfare improvements. In the event a holder and other users of a public right-of-way, including incumbent cable operators or utilities, are required to relocate and compensation is paid to the users of such public right-of-way, such parties shall be treated equally with respect to such compensation.

(5) The holder shall comply with all local units of government inspection requirements. The making of post-construction, subsequent or periodic inspections, or both, or the failure to do so shall not operate to relieve the holder of any responsibility, obligation, or liability.

(6) The holder shall maintain insurance or provide evidence of self insurance as required by an applicable ordinance of the local unit of government.

(7) The holder shall reimburse all reasonable make-ready expenses, including aerial and underground installation expenses requested by the holder to the local unit of government within 30 days of billing to the holder, provided that such charges shall be at the same rates as charges to others for the same or similar services.

(8) The holder shall indemnify and hold harmless the local unit of government and all boards, officers, employees, and representatives thereof from all claims, demands, causes of action, liability, judgments, costs and expenses, or losses for injury or death to persons or damage to property owned by, and Worker's Compensation claims against any parties indemnified herein, arising out of, caused by, or as a result of the holder's construction, lines, cable, erection, maintenance, use or presence of, or removal of any poles, wires, conduit, appurtenances thereto, or equipment or attachments thereto. The holder, however, shall not indemnify the local unit of government for any liabilities, damages, cost, and expense resulting from the willful misconduct, or negligence of the local unit of government, its officers, employees, and agents. The obligations imposed pursuant to this Section by a local unit of government shall be competitively neutral.

(9) The holder, upon request, shall provide the local unit of government with information describing the location of the cable service or video service facilities and equipment located in the unit of local government's rights-of-way pursuant to its State-issued authorization. If designated by the holder as confidential, such information provided pursuant to this subsection shall be exempt from inspection and copying under the Freedom of Information Act and shall not be disclosed by the unit of local government to any third party without the written consent of the holder.

(Source: P.A. 99-6, eff. 6-29-15; 100-20, eff. 7-1-17.)

(220 ILCS 5/21-1101)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-1101. Requirements to provide video services.

(a) The holder of a State-issued authorization shall not deny access to cable service or video service to any potential residential subscribers because of the race or income of the residents in the local area in which the potential subscribers reside.

(b) (Blank).

(c)(1) If the holder of a State-issued authorization is using telecommunications facilities to provide cable or video service and has more than 1,000,000 telecommunications access lines in this State, the holder shall provide access to its cable or video service to a number of households equal to at least 35% of the households in the holder's telecommunications service area in the State within 3 years after the date a holder receives a State-issued authorization from the Commission and to a number not less than 50% of these households within 5 years after the date a holder receives a State-issued authorization from the Commission; provided that the holder of a State-issued authorization is not required to meet the 50% requirement in this paragraph (1) until 2 years after at least 15% of the households with access to the holder's video service subscribe to the service for 6 consecutive months.

The holder's obligation to provide such access in the State shall be distributed, as the holder determines, within 3 designated market areas, one in each of the northeastern, central, and southwestern portions of the holder's telecommunications service area in the State. The designated market area for the northeastern portion shall consist of 2 separate and distinct reporting areas: (i) a city with more than 1,000,000 inhabitants, and (ii) all other local units of government on a combined basis within such designated market area in which it offers video service.

If any state, in which a holder subject to this subsection (c) or one of its affiliates provides or seeks to provide cable or video service, adopts a law permitting state-issued authorization or statewide franchises to provide cable or video service that requires a cable or video provider to offer service to more than 35% of the households in the cable or video provider's service area in that state within 3 years, holders subject to this subsection (c) shall provide service in this State to the same percentage of households within 3 years of adoption of such law in that state.

Furthermore, if any state, in which a holder subject to this subsection (c) or one of its affiliates provides or seeks to provide cable or video service, adopts a law requiring a holder of a state-issued authorization or statewide franchises to offer cable or video service to more than 35% of its households if less than 15% of the households with access to the holder's video service subscribe to the service for 6 consecutive months, then as a precondition to further build-out, holders subject to this subsection (c) shall be subject to the same percentage of service subscription in meeting its obligation to provide service to 50% of the households in this State.

(2) Within 3 years after the date a holder receives a State-issued authorization from the Commission, at least 30% of the total households with access to the holder's cable or video service shall be low-income.

Within each designated market area listed in paragraph (1) of this subsection (c), the holder's obligation to offer service to low-income households shall be measured by each exchange, as that term is defined in Section 13-206 of this Act in which the holder chooses to provide cable or video service. The holder is under no obligation to serve or provide access to an entire exchange; however, in addition to the statewide obligation to provide low-income access provided by this Section, in each exchange in which the holder chooses to provide cable or video service, the holder shall provide access to a percentage of low-income households that is at least equal to the percentage of the total low-income households within that exchange.

(d)(1) All other holders shall only provide access to one or more exchanges, as that term is defined in Section 13-206 of this Act, or to local units of government and shall provide access to their cable or video service to a number of households equal to 35% of the households in the exchange or local unit of government within 3 years after the date a holder receives a State-issued authorization from the Commission and to a number not less than 50% of these households within 5 years after the date a holder receives a State-issued authorization from the Commission, provided that if the holder is an incumbent cable operator or any successor-in-interest company, it shall be obligated to provide access to cable or video services within the jurisdiction of a local unit of government at the same levels required by the local franchising authorities for that local unit of government on June 30, 2007 (the effective date of Public Act 95-9).

(2) Within 3 years after the date a holder receives a State-issued authorization from the Commission, at least 30% of the total households with access to the holder's cable or video service shall be low-income.

Within each designated exchange, as that term is defined in Section 13-206 of this Act, or local unit of government listed in paragraph (1) of this subsection (d), the holder's obligation to offer service to low-income households shall be measured by each exchange or local unit of government in which the holder chooses to provide cable or video service. Except as provided in paragraph (1) of this subsection (d), the holder is under no obligation to serve or provide access to an entire exchange or local unit of government; however, in addition to the statewide obligation to provide low-income access provided by this Section, in each exchange or local unit of government in which the holder chooses to provide cable or video service, the holder shall provide access to a percentage of low-income households that is at least equal to the percentage of the total low-income households within that exchange or local unit of government.

(e) A holder subject to subsection (c) of this Section shall provide wireline broadband service, defined as wireline service, capable of supporting, in at least one direction, a speed in excess of 200 kilobits per second (kbps), to the network demarcation point at the subscriber's premises, to a number of households equal to 90% of the households in the holder's telecommunications service area by December 31, 2008, or shall pay within 30 days of December 31, 2008 a sum of $15,000,000 to the Digital Divide Elimination Infrastructure Fund established pursuant to Section 13-301.3 of this Act, or any successor fund established by the General Assembly. In that event the holder is required to make a payment pursuant to this subsection (e), the holder shall have no further accounting for this payment, which shall be used in any part of the State for the purposes established in the Digital Divide Elimination Infrastructure Fund or for broadband deployment.

(f) The holder of a State-issued authorization may satisfy the requirements of subsections (c) and (d) of this Section through the use of any technology, which shall not include direct-to-home satellite service, that offers service, functionality, and content that is demonstrably similar to that provided through the holder's video service system.

(g) In any investigation into or complaint alleging that the holder of a State-issued authorization has failed to meet the requirements of this Section, the following factors may be considered in justification or mitigation or as justification for an extension of time to meet the requirements of subsections (c) and (d) of this Section:

(1) The inability to obtain access to public and private rights-of-way under reasonable terms and conditions.

(2) Barriers to competition arising from existing exclusive service arrangements in developments or buildings.

(3) The inability to access developments or buildings using reasonable technical solutions under commercially reasonable terms and conditions.

(4) Natural disasters.

(5) Other factors beyond the control of the holder.

(h) If the holder relies on the factors identified in subsection (g) of this Section in response to an investigation or complaint, the holder shall demonstrate the following:

(1) what substantial effort the holder of a State-issued authorization has taken to meet the requirements of subsection (a) or (c) of this Section;

(2) which portions of subsection (g) of this Section apply; and

(3) the number of days it has been delayed or the requirements it cannot perform as a consequence of subsection (g) of this Section.

(i) The factors in subsection (g) of this Section may be considered by the Attorney General or by a court of competent jurisdiction in determining whether the holder is in violation of this Article.

(j) Every holder of a State-issued authorization, no later than April 1, 2009, and annually no later than April 1 thereafter, shall report to the Commission for each of the service areas as described in subsections (c) and (d) of this Section in which it provides access to its video service in the State, the following information:

(1) Cable service and video service information:

(A) The number of households in the holder's telecommunications service area within each designated market area as described in subsection (c) of this Section or exchange or local unit of government as described in subsection (d) of this Section in which it offers video service.

(B) The number of households in the holder's telecommunications service area within each designated market area as described in subsection (c) of this Section or exchange or local unit of government as described in subsection (d) of this Section that are offered access to video service by the holder.

(C) The number of households in the holder's telecommunications service area in the State.

(D) The number of households in the holder's telecommunications service area in the State that are offered access to video service by the holder.

(2) Low-income household information:

(A) The number of low-income households in the holder's telecommunications service area within each designated market area as described in subsection (c) of this Section, as further identified in terms of exchanges, or exchange or local unit of government as described in subsection (d) of this Section in which it offers video service.

(B) The number of low-income households in the holder's telecommunications service area within each designated market area as described in subsection (c) of this Section, as further identified in terms of exchanges, or exchange or local unit of government as described in subsection (d) of this Section in the State that are offered access to video service by the holder.

(C) The number of low-income households in the holder's telecommunications service area in the State.

(D) The number of low-income households in the holder's telecommunications service area in the State that are offered access to video service by the holder.

(j-5) The requirements of subsection (c) of this Section shall be satisfied upon the filing of an annual report with the Commission in compliance with subsection (j) of this Section, including an annual report filed prior to this amendatory Act of the 98th General Assembly, that demonstrates the holder of the authorization has satisfied the requirements of subsection (c) of this Section for each of the service areas in which it provides access to its cable service or video service in the State. Notwithstanding the continued application of this Article to the holder, upon satisfaction of the requirements of subsection (c) of this Section, only the requirements of subsection (a) of this Section 21-1101 of this Act and the following reporting requirements shall continue to apply to such holder:

(1) Cable service and video service information:

(A) The number of households in the holder's telecommunications service area within each designated market area in which it offers cable service or video service.

(B) The number of households in the holder's telecommunications service area within each designated market area that are offered access to cable service or video service by the holder.

(C) The number of households in the holder's telecommunications service area in the State.

(D) The number of households in the holder's telecommunications service area in the State that are offered access to cable service or video service by the holder.

(E) The exchanges or local units of government in which the holder added cable service or video service in the prior year.

(2) Low-income household information:

(A) The number of low-income households in the holder's telecommunications service area within each designated market area in which it offers video service.

(B) The number of low-income households in the holder's telecommunications service area within each designated market area that are offered access to video service by the holder.

(C) The number of low-income households in the holder's telecommunications service area in the State.

(D) The number of low-income households in the holder's telecommunications service area in the State that are offered access to video service by the holder.

(j-10) The requirements of subsection (d) of this Section shall be satisfied upon the filing of an annual report with the Commission in compliance with subsection (j) of this Section, including an annual report filed prior to this amendatory Act of the 98th General Assembly, that demonstrates the holder of the authorization has satisfied the requirements of subsection (d) of this Section for each of the service areas in which it provides access to its cable service or video service in the State. Notwithstanding the continued application of this Article to the holder, upon satisfaction of the requirements of subsection (d) of this Section, only the requirements of subsection (a) of this Section and the following reporting requirements shall continue to apply to such holder:

(1) Cable service and video service information:

(A) The number of households in the holder's footprint in which it offers cable service or video service.

(B) The number of households in the holder's footprint that are offered access to cable service or video service by the holder.

(C) The exchanges or local units of government in which the holder added cable service or video service in the prior year.

(2) Low-income household information:

(A) The number of low-income households in the holder's footprint in which it offers cable service or video service.

(B) The number of low-income households in the holder's footprint that are offered access to cable service or video service by the holder.

(k) The Commission, within 30 days of receiving the first report from holders under this Section, and annually no later than July 1 thereafter, shall submit to the General Assembly a report that includes, based on year-end data, the information submitted by holders pursuant to subdivisions (1) and (2) of subsections (j), (j-5), and (j-10) of this Section. The Commission shall make this report available to any member of the public or any local unit of government upon request. All information submitted to the Commission and designated by holders as confidential and proprietary shall be subject to the disclosure provisions in subsection (c) of Section 21-401 of this Act. No individually identifiable customer information shall be subject to public disclosure.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-1201)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-1201. Multiple-unit dwellings; interference with holder prohibited.

(a) Neither the owner of any multiple-unit residential dwelling nor an agent or representative nor an assignee, grantee, licensee, or similar holders of rights, including easements, in any multiple-unit residential dwelling (the "owner, agent or representative") shall unreasonably interfere with the right of any tenant or lawful resident thereof to receive cable service or video service installation or maintenance from a holder of a State-issued authorization, or related service that includes, but is not limited to, voice service, Internet access or other broadband services (alone or in combination) provided over the holder's cable services or video services facilities; provided, however, the owner, agent, or representative may require just and reasonable compensation from the holder for its access to and use of such property to provide installation, operation, maintenance, or removal of such cable service or video service or related services. For purposes of this Section, "access to and use of such property" shall be provided in a nondiscriminatory manner to all cable and video providers offering or providing services at such property and includes common areas of such multiple-unit dwelling, inside wire in the individual unit of any tenant or lawful resident thereof that orders or receives such service and the right to use and connect to building infrastructure, including but not limited to existing cables, wiring, conduit or inner duct, to provide cable service or video service or related services. If there is a dispute regarding the just compensation for such access and use, the owner, agent, or representative shall obtain the payment of just compensation from the holder pursuant to the process and procedures applicable to an owner and franchisee in subsections (c), (d), and (e) of Section 11-42-11.1 of the Illinois Municipal Code (65 ILCS 5/11-42-11.1).

(b) Neither the owner of any multiple-unit residential dwelling nor an agent or representative shall ask, demand, or receive any additional payment, service, or gratuity in any form from any tenant or lawful resident thereof as a condition for permitting or cooperating with the installation of a cable service or video service or related services to the dwelling unit occupied by a tenant or resident requesting such service.

(c) Neither the owner of any multiple-unit residential dwelling nor an agent or representative shall penalize, charge, or surcharge a tenant or resident, forfeit or threaten to forfeit any right of such tenant or resident, or discriminate in any way against such tenant or resident who requests or receives cable service or video service or related services from a holder.

(d) Nothing in this Section shall prohibit the owner of any multiple-unit residential dwelling nor an agent or representative from requiring that a holder's facilities conform to reasonable conditions necessary to protect safety, functioning, appearance, and value of premises or the convenience and safety of persons or property.

(e) The owner of any multiple-unit residential dwelling or an agent or representative may require a holder to agree to indemnify the owner, or his agents or representatives, for damages or from liability for damages caused by the installation, operation, maintenance, or removal of cable service or video service facilities.

(f) For purposes of this Section, "multiple-unit dwelling" or "such property" means a multiple dwelling unit building (such as an apartment building, condominium building, or cooperative) and any other centrally managed residential real estate development (such as a gated community, mobile home park, or garden apartment); provided however, that multiple-unit dwelling shall not include time share units, academic campuses and dormitories, military bases, hotels, rooming houses, prisons, jails, halfway houses, nursing homes or other assisted living facilities, and hospitals.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-1301)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-1301. Enforcement; penalties.

(a) The Attorney General is responsible for administering and ensuring holders' compliance with this Article, provided that nothing in this Article shall deprive local units of government of the right to enforce applicable rights and obligations.

(b) The Attorney General may conduct an investigation regarding possible violations by holders of this Article including, without limitation, the issuance of subpoenas to:

(1) require the holder to file a statement or report or to answer interrogatories in writing as to all information relevant to the alleged violations;

(2) examine, under oath, any person who possesses knowledge or information related to the alleged violations; and

(3) examine any record, book, document, account, or paper related to the alleged violation.

(c) If the Attorney General determines that there is a reason to believe that a holder has violated or is about to violate this Article, the Attorney General may bring an action in a court of competent jurisdiction in the name of the People of the State against the holder to obtain temporary, preliminary, or permanent injunctive relief and civil penalties for any act, policy, or practice by the holder that violates this Article.

(d) If a court orders a holder to make payments to the Attorney General and the payments are to be used for the operations of the Office of the Attorney General or if a holder agrees to make payments to the Attorney General for the operations of the Office of the Attorney General as part of an Assurance of Voluntary Compliance, then the moneys paid under any of the conditions described in this subsection (d) shall be deposited into the Attorney General Court Ordered and Voluntary Compliance Payment Projects Fund. Moneys in the Fund shall be used, subject to appropriation, for the performance of any function pertaining to the exercise of the duties to the Attorney General, including, but not limited to, enforcement of any law of this State and conducting public education programs; however, any moneys in the Fund that are required by the court to be used for a particular purpose shall be used for that purpose.

(e) In an action against a holder brought pursuant to this Article, the Attorney General may seek the assessment of one or more of the following civil monetary penalties in any action filed under this Article where the holder violates this Article and does not remedy the violation within 30 days of notice by the Attorney General:

(1) Any holder that violates or fails to comply with any of the provisions of this Article or of its State-issued authorization shall be subject to a civil penalty of up to $30,000 for each and every offense, or 0.00825% of the holder's gross revenues, as defined in Section 21-801 of this Act, whichever is greater. Every violation of the provisions of this Article by a holder is a separate and distinct offense, provided that if the same act or omission violates more than one provision of this Article, only one penalty or cumulative penalty may be imposed for such act or omission. In the case of a continuing violation, each day's continuance thereof shall be a separate and distinct offense, provided that the cumulative penalty for any continuing violation shall not exceed $500,000 per year, and provided further that these limits shall not apply where the violation was intentional and either (i) created substantial risk to the safety of the cable service or video service provider's employees or customers or the public or (ii) was intended to cause economic benefits to accrue to the violator.

(2) The holder's State-issued authorization may be suspended or revoked if the holder fails to comply with the provisions of this Article after a reasonable time to achieve compliance has passed.

(3) If the holder is in violation of Section 21-1101 of this Act, in addition to any other remedies provided by law, a fine not to exceed 3% of the holder's total monthly gross revenue, as that term is defined in this Article, shall be imposed for each month from the date of violation until the date that compliance is achieved.

(4) Nothing in this Section shall limit or affect the powers of the Attorney General to enforce the provisions of this Article, Section 22-501 of this Act, or the Consumer Fraud and Deceptive Business Practices Act.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-1401)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-1401. Home rule.

(a) The provisions of this Article are a limitation of home rule powers under subsection (i) of Section 6 of Article VII of the Illinois Constitution.

(b) Nothing in this Article shall be construed to limit or deny a home rule unit's power to tax as set forth in Section 6 of Article VII of the Illinois Constitution.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-1501)

(Section scheduled to be repealed on January 1, 2030)

Sec. 21-1501. Except as otherwise provided in this Article, this Article shall be enforced only by a court of competent jurisdiction.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-1502)

Sec. 21-1502. Renewal upon repeal of Article. This Section shall apply only to holders who received their State-issued authorization as a cable operator. In the event this Article 21 is repealed, the cable operator may seek a renewal under 47 U.S.C. 546 subject to the following:

(1) Each municipality or county in which a cable operator provided service under the State-issued authorization shall be the franchising authority with respect to any right of renewal under 47 U.S.C. 546 and the provisions of this Section shall apply during the renewal process.

(2) If the cable operator was an incumbent cable operator in the local unit of government immediately prior to obtaining a State-issued authorization, then the terms of the local franchise agreement under which the incumbent cable operator operated shall be effective until the later of: (A) the expiration of what would have been the remaining term of the agreement at the time of the termination of the local franchise agreement pursuant to subsection (c) of Section 21-301 of this Act or (B) the expiration of the renewal process under 47 U.S.C. 546.

(3) If the cable operator was not an incumbent cable operator in the service territory immediately prior to the issuance of the State-issued authorization, then the State-issued authorization shall continue in effect until the expiration of the renewal process under 47 U.S.C. 546.

(4) In seeking a renewal under this Section, the cable operator must provide the following information to the local franchising authority:

(A) the number of subscribers within the franchise area;

(B) the number of eligible local government buildings that have access to cable services;

(C) the statistical records of performance under the standards established by the Cable and Video Customer Protection Law;

(D) cable system improvement and construction plans during the term of the proposed franchise; and

(E) the proposed level of support for public, educational, and governmental access programming.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-1503)

Sec. 21-1503. Continuation of Article; validation.

(a) The General Assembly finds and declares that this amendatory Act of the 100th General Assembly manifests the intention of the General Assembly to extend the repeal of this Article and have this Article continue in effect until December 31, 2020.

(b) This Article shall be deemed to have been in continuous effect since July 1, 2017 and it shall continue to be in effect henceforward until it is otherwise lawfully repealed. All previously enacted amendments to this Article taking effect on or after July 1, 2017, are hereby validated. All actions taken in reliance on or under this Article by the Illinois Commerce Commission or any other person or entity are hereby validated.

(c) In order to ensure the continuing effectiveness of this Article, it is set forth in full and reenacted by this amendatory Act of the 100th General Assembly. Striking and underscoring are used only to show changes being made to the base text. This reenactment is intended as a continuation of this Article. It is not intended to supersede any amendment to this Article that is enacted by the 100th General Assembly.

(Source: P.A. 100-20, eff. 7-1-17.)

(220 ILCS 5/21-1601)

Sec. 21-1601. Repealer. Sections 21-101 through 21-1501 of this Article are repealed January 1, 2030.

(Source: P.A. 102-9, eff. 6-3-21; 103-601, eff. 7-1-24.)

(220 ILCS 5/Art. XXII heading) ARTICLE XXII. CABLE AND VIDEO CUSTOMER PROTECTION LAW (Source: P.A. 95-9, eff. 6-30-07; 95-876, eff. 8-21-08.)

(220 ILCS 5/22-501)

Sec. 22-501. Customer service and privacy protection. All cable or video providers in this State shall comply with the following customer service requirements and privacy protections. The provisions of this Act shall not apply to an incumbent cable operator prior to January 1, 2008. For purposes of this paragraph, an incumbent cable operator means a person or entity that provided cable services in a particular area under a franchise agreement with a local unit of government pursuant to Section 11-42-11 of the Illinois Municipal Code or Section 5-1095 of the Counties Code on January 1, 2007. A master antenna television, satellite master antenna television, direct broadcast satellite, multipoint distribution service, and other provider of video programming shall only be subject to the provisions of this Article to the extent permitted by federal law.

The following definitions apply to the terms used in this Article:

"Basic cable or video service" means any service offering or tier that includes the retransmission of local television broadcast signals.

"Cable or video provider" means any person or entity providing cable service or video service pursuant to authorization under (i) the Cable and Video Competition Law of 2007; (ii) Section 11-42-11 of the Illinois Municipal Code; (iii) Section 5-1095 of the Counties Code; or (iv) a master antenna television, satellite master antenna television, direct broadcast satellite, multipoint distribution services, and other providers of video programming, whatever their technology. A cable or video provider shall not include a landlord providing only broadcast video programming to a single-family home or other residential dwelling consisting of 4 units or less.

"Franchise" has the same meaning as found in 47 U.S.C. 522(9).

"Local unit of government" means a city, village, incorporated town, or a county.

"Normal business hours" means those hours during which most similar businesses in the geographic area of the local unit of government are open to serve customers. In all cases, "normal business hours" must include some evening hours at least one night per week or some weekend hours.

"Normal operating conditions" means those service conditions that are within the control of cable or video providers. Those conditions that are not within the control of cable or video providers include, but are not limited to, natural disasters, civil disturbances, power outages, telephone network outages, and severe or unusual weather conditions. Those conditions that are ordinarily within the control of cable or video providers include, but are not limited to, special promotions, pay-per-view events, rate increases, regular peak or seasonal demand periods, and maintenance or upgrade of the cable service or video service network.

"Service interruption" means the loss of picture or sound on one or more cable service or video service on one or more cable or video channels.

"Service line drop" means the point of connection between a premises and the cable or video network that enables the premises to receive cable service or video service.

(a) General customer service standards:

(1) Cable or video providers shall establish general standards related to customer service, which shall include, but not be limited to, installation, disconnection, service and repair obligations; appointment hours and employee ID requirements; customer service telephone numbers and hours; procedures for billing, charges, deposits, refunds, and credits; procedures for termination of service; notice of deletion of programming service; changes related to transmission of programming; changes or increases in rates; the use and availability of parental control or lock-out devices; the use and availability of an A/B switch if applicable; complaint procedures and procedures for bill dispute resolution; a description of the rights and remedies available to consumers if the cable or video provider does not materially meet its customer service standards; and special services for customers with visual, hearing, or mobility disabilities.

(2) Cable or video providers' rates for each level of service, rules, regulations, and policies related to its cable service or video service described in paragraph (1) of this subsection (a) must be made available to the public and displayed clearly and conspicuously on the cable or video provider's site on the Internet. If a promotional price or a price for a specified period of time is offered, the cable or video provider shall display the price at the end of the promotional period or specified period of time clearly and conspicuously with the display of the promotional price or price for a specified period of time. The cable or video provider shall provide this information upon request.

(3) Cable or video providers shall provide notice concerning their general customer service standards to all customers. This notice shall be offered when service is first activated and upon request thereafter. The information in the notice shall also be available on the cable or video providers' websites and shall include all of the information specified in paragraph (1) of this subsection (a), as well as the following: a listing of services offered by the cable or video providers, which shall clearly describe programming for all services and all levels of service; the rates for all services and levels of service; a telephone number through which customers may subscribe to, change, or terminate service, request customer service, or seek general or billing information; instructions on the use of the cable or video services; and a description of rights and remedies that the cable or video providers shall make available to their customers if they do not materially meet the general customer service standards described in this Act.

(b) General customer service obligations:

(1) Cable or video providers shall render reasonably efficient service, promptly make repairs, and interrupt service only as necessary and for good cause, during periods of minimum use of the system and for no more than 24 hours.

(2) All service representatives or any other person who contacts customers or potential customers on behalf of the cable or video provider shall have a visible identification card with their name and photograph and shall orally identify themselves upon first contact with the customer. Customer service representatives shall orally identify themselves to callers immediately following the greeting during each telephone contact with the public.

(3) The cable or video providers shall: (i) maintain a customer service facility within the boundaries of a local unit of government staffed by customer service representatives that have the capacity to accept payment, adjust bills, and respond to repair, installation, reconnection, disconnection, or other service calls and distribute or receive converter boxes, remote control units, digital stereo units, or other equipment related to the provision of cable or video service; (ii) provide customers with bill payment facilities through retail, financial, or other commercial institutions located within the boundaries of a local unit of government; (iii) provide an address, toll-free telephone number or electronic address to accept bill payments and correspondence and provide secure collection boxes for the receipt of bill payments and the return of equipment, provided that if a cable or video provider provides secure collection boxes, it shall provide a printed receipt when items are deposited; or (iv) provide an address, toll-free telephone number, or electronic address to accept bill payments and correspondence and provide a method for customers to return equipment to the cable or video provider at no cost to the customer.

(4) In each contact with a customer, the service representatives or any other person who contacts customers or potential customers on behalf of the cable or video provider shall state the estimated cost of the service, repair, or installation orally prior to delivery of the service or before any work is performed, shall provide the customer with an oral statement of the total charges before terminating the telephone call or other contact in which a service is ordered, whether in-person or over the Internet, and shall provide a written statement of the total charges before leaving the location at which the work was performed. In the event that the cost of service is a promotional price or is for a limited period of time, the cost of service at the end of the promotion or limited period of time shall be disclosed.

(5) Cable or video providers shall provide customers a minimum of 30 days' written notice before increasing rates or eliminating transmission of programming and shall submit the notice of any rate increase to the local unit of government in advance of distribution to customers, provided that the cable or video provider is not in violation of this provision if the elimination of transmission of programming was outside the control of the provider, in which case the provider shall use reasonable efforts to provide as much notice as possible, and any rate decrease related to the elimination of transmission of programming shall be applied to the date of the change.

(6) Cable or video providers shall provide clear visual and audio reception that meets or exceeds applicable Federal Communications Commission technical standards. If a customer experiences poor video or audio reception due to the equipment of the cable or video provider, the cable or video provider shall promptly repair the problem at its own expense.

(c) Bills, payment, and termination:

(1) Cable or video providers shall render monthly bills that are clear, accurate, and understandable.

(2) Every residential customer who pays bills directly to the cable or video provider shall have at least 28 days from the date of the bill to pay the listed charges.

(3) Customer payments shall be posted promptly. When the payment is sent by United States mail, payment is considered paid on the date it is postmarked.

(4) Cable or video providers may not terminate residential service for nonpayment of a bill unless the cable or video provider furnishes notice of the delinquency and impending termination at least 15 days prior to the proposed termination. Notice of proposed termination shall be mailed, postage prepaid, to the customer to whom service is billed. Notice of proposed termination shall not be mailed until the 24th day after the date of the bill for services. Notice of delinquency and impending termination may be part of a billing statement only if the notice is designed to be conspicuous. The cable or video providers may not assess a late fee prior to the 24th day after the date of the bill for service.

(5) Every notice of impending termination shall include all of the following: the name and address of customer; the amount of the delinquency; the date on which payment is required to avoid termination; and the telephone number of the cable or video provider's service representative to make payment arrangements and to provide additional information about the charges for failure to return equipment and for reconnection, if any.

(6) Service may only be terminated on days when the customer is able to reach a service representative of the cable or video providers, either in person or by telephone.

(7) Any service terminated by a cable or video provider without good cause shall be restored without any reconnection fee, charge, or penalty; good cause for termination includes, but is not limited to, failure to pay a bill by the date specified in the notice of impending termination, payment by check for which there are insufficient funds, theft of service, abuse of equipment or personnel, or other similar subscriber actions.

(8) Cable or video providers shall cease charging a customer for any or all services within one business day after it receives a request to immediately terminate service or on the day requested by the customer if such a date is at least 5 days from the date requested by the customer. Nothing in this subsection (c) shall prohibit the provider from billing for charges that the customer incurs prior to the date of termination. Cable or video providers shall issue a credit no later than the customer's next billing cycle following the determination that a credit is warranted. Cable or video providers shall issue a refund or return a deposit promptly, but not later than either the customer's next billing cycle following resolution of the request or 30 days, whichever is earlier, or the return of equipment, if any, whichever is later.

(9) The customers or subscribers of a cable or video provider shall be allowed to disconnect their service at any time within the first 30 days after subscribing to or upgrading the service. Within this 30-day period, cable or video providers shall not charge or impose any fees or penalties on the customer for disconnecting service, including, but not limited to, any installation charge or the imposition of an early termination charge, except the cable or video provider may impose a charge or fee to offset any rebates or credits received by the customer and may impose monthly service or maintenance charges, including pay-per-view and premium services charges, during such 30-day period.

(d) Response to customer inquiries:

(1) Cable or video providers will maintain a toll-free telephone access line that is available to customers 24 hours a day, 7 days a week to accept calls regarding installation, termination, service, and complaints. Trained, knowledgeable, qualified service representatives of the cable or video providers will be available to respond to customer telephone inquiries during normal business hours. Customer service representatives shall be able to provide credit, waive fees, schedule appointments, and change billing cycles. Any difficulties that cannot be resolved by the customer service representatives shall be referred to a supervisor who shall make his or her best efforts to resolve the issue immediately. If the supervisor does not resolve the issue to the customer's satisfaction, the customer shall be informed of the cable or video provider's complaint procedures and procedures for billing dispute resolution and given a description of the rights and remedies available to customers to enforce the terms of this Article, including the customer's rights to have the complaint reviewed by the local unit of government, to request mediation, and to review in a court of competent jurisdiction.

(2) After normal business hours, the access line may be answered by a service or an automated response system, including an answering machine. Inquiries received by telephone or e-mail after normal business hours shall be responded to by a trained service representative on the next business day. The cable or video provider shall respond to a written billing inquiry within 10 days of receipt of the inquiry.

(3) Cable or video providers shall provide customers seeking non-standard installations with a total installation cost estimate and an estimated date of completion. The actual charge to the customer shall not exceed the estimated cost without the written consent of the customer.

(4) If the cable or video provider receives notice that an unsafe condition exists with respect to its equipment, it shall investigate such condition immediately and shall take such measures as are necessary to remove or eliminate the unsafe condition. The cable or video provider shall inform the local unit of government promptly, but no later than 2 hours after it receives notification of an unsafe condition that it has not remedied.

(5) Under normal operating conditions, telephone answer time by the cable or video provider's customer representative, including wait time, shall not exceed 30 seconds when the connection is made. If the call needs to be transferred, transfer time shall not exceed 30 seconds. These standards shall be met no less than 90% of the time under normal operating conditions, measured on a quarterly basis. The cable or video provider shall not be required to acquire equipment or perform surveys to measure compliance with these telephone answering standards unless an historical record of complaints indicates a clear failure to comply.

(6) Under normal operating conditions, the cable or video provider's customers will receive a busy signal less than 3% of the time.

(e) Under normal operating conditions, each of the following standards related to installations, outages, and service calls will be met no less than 95% of the time measured on a quarterly basis:

(1) Standard installations will be performed within 7 business days after an order has been placed. "Standard" installations are those that are located up to 125 feet from the existing distribution system.

(2) Excluding conditions beyond the control of the cable or video providers, the cable or video providers will begin working on "service interruptions" promptly and in no event later than 24 hours after the interruption is reported by the customer or otherwise becomes known to the cable or video providers. Cable or video providers must begin actions to correct other service problems the next business day after notification of the service problem and correct the problem.

(3) The "appointment window" alternatives for installations, service calls, and other installation activities will be either a specific time or, at a maximum, a 4-hour time block during evening, weekend, and normal business hours. The cable or video provider may schedule service calls and other installation activities outside of these hours for the express convenience of the customer.

(4) Cable or video providers may not cancel an appointment with a customer after the close of business on the business day prior to the scheduled appointment. If the cable or video provider's representative is running late for an appointment with a customer and will not be able to keep the appointment as scheduled, the customer will be contacted. The appointment will be rescheduled, as necessary, at a time that is convenient for the customer, even if the rescheduled appointment is not within normal business hours.

(f) Public benefit obligation:

(1) All cable or video providers offering service pursuant to the Cable and Video Competition Law of 2007, the Illinois Municipal Code, or the Counties Code shall provide a free service line drop and free basic service to all current and future public buildings within their footprint, including, but not limited to, all local unit of government buildings, public libraries, and public primary and secondary schools, whether owned or leased by that local unit of government ("eligible buildings"). Such service shall be used in a manner consistent with the government purpose for the eligible building and shall not be resold.

(2) This obligation only applies to those cable or video service providers whose cable service or video service systems pass eligible buildings and its cable or video service is generally available to residential subscribers in the same local unit of government in which the eligible building is located. The burden of providing such service at each eligible building shall be shared by all cable and video providers whose systems pass the eligible buildings in an equitable and competitively neutral manner, and nothing herein shall require duplicative installations by more than one cable or video provider at each eligible building. Cable or video providers operating in a local unit of government shall meet as necessary and determine who will provide service to eligible buildings under this subsection (f). If the cable or video providers are unable to reach an agreement, they shall meet with the local unit of government, which shall determine which cable or video providers will serve each eligible building. The local unit of government shall bear the costs of any inside wiring or video equipment costs not ordinarily provided as part of the cable or video provider's basic offering.

(g) After the cable or video providers have offered service for one year, the cable or video providers shall make an annual report to the Commission, to the local unit of government, and to the Attorney General that it is meeting the standards specified in this Article, identifying the number of complaints it received over the prior year in the State and specifying the number of complaints related to each of the following: (1) billing, charges, refunds, and credits; (2) installation or termination of service; (3) quality of service and repair; (4) programming; and (5) miscellaneous complaints that do not fall within these categories.

(h) To the extent consistent with federal law, cable or video providers shall offer the lowest-cost basic cable or video service as a stand-alone service to residential customers at reasonable rates. Cable or video providers shall not require the subscription to any service other than the lowest-cost basic service or to any telecommunications or information service, as a condition of access to cable or video service, including programming offered on a per channel or per program basis. Cable or video providers shall not discriminate between subscribers to the lowest-cost basic service, subscribers to other cable services or video services, and other subscribers with regard to the rates charged for cable or video programming offered on a per channel or per program basis.

(i) To the extent consistent with federal law, cable or video providers shall ensure that charges for changes in the subscriber's selection of services or equipment shall be based on the cost of such change and shall not exceed nominal amounts when the system's configuration permits changes in service tier selection to be effected solely by coded entry on a computer terminal or by other similarly simple method.

(j) To the extent consistent with federal law, cable or video providers shall have a rate structure for the provision of cable or video service that is uniform throughout the area within the boundaries of the local unit of government. This subsection (j) is not intended to prohibit bulk discounts to multiple dwelling units or to prohibit reasonable discounts to senior citizens or other economically disadvantaged groups.

(k) To the extent consistent with federal law, cable or video providers shall not charge a subscriber for any service or equipment that the subscriber has not affirmatively requested or affirmatively agreed to by name. For purposes of this subsection (k), a subscriber's failure to refuse a cable or video provider's proposal to provide service or equipment shall not be deemed to be an affirmative request for such service or equipment.

(l) No contract or service agreement containing an early termination clause offering residential cable or video services or any bundle including such services shall be for a term longer than 2 years. Any contract or service offering with a term of service that contains an early termination fee shall limit the early termination fee to not more than the value of any additional goods or services provided with the cable or video services, the amount of the discount reflected in the price for cable services or video services for the period during which the consumer benefited from the discount, or a declining fee based on the remainder of the contract term.

(m) Cable or video providers shall not discriminate in the provision of services for the hearing and visually impaired, and shall comply with the accessibility requirements of 47 U.S.C. 613. Cable or video providers shall deliver and pick-up or provide customers with pre-paid shipping and packaging for the return of converters and other necessary equipment at the home of customers with disabilities. Cable or video providers shall provide free use of a converter or remote control unit to mobility impaired customers.

(n)(1) To the extent consistent with federal law, cable or video providers shall comply with the provisions of 47 U.S.C. 532(h) and (j). The cable or video providers shall not exercise any editorial control over any video programming provided pursuant to this Section, or in any other way consider the content of such programming, except that a cable or video provider may refuse to transmit any leased access program or portion of a leased access program that contains obscenity, indecency, or nudity and may consider such content to the minimum extent necessary to establish a reasonable price for the commercial use of designated channel capacity by an unaffiliated person. This subsection (n) shall permit cable or video providers to enforce prospectively a written and published policy of prohibiting programming that the cable or video provider reasonably believes describes or depicts sexual or excretory activities or organs in a patently offensive manner as measured by contemporary community standards.

(2) Upon customer request, the cable or video provider shall, without charge, fully scramble or otherwise fully block the audio and video programming of each channel carrying such programming so that a person who is not a subscriber does not receive the channel or programming.

(3) In providing sexually explicit adult programming or other programming that is indecent on any channel of its service primarily dedicated to sexually oriented programming, the cable or video provider shall fully scramble or otherwise fully block the video and audio portion of such channel so that a person who is not a subscriber to such channel or programming does not receive it.

(4) Scramble means to rearrange the content of the signal of the programming so that the programming cannot be viewed or heard in an understandable manner.

(o) Cable or video providers will maintain a listing, specific to the level of street address, of the areas where its cable or video services are available. Customers who inquire about purchasing cable or video service shall be informed about whether the cable or video provider's cable or video services are currently available to them at their specific location.

(p) Cable or video providers shall not disclose the name, address, telephone number or other personally identifying information of a cable service or video service customer to be used in mailing lists or to be used for other commercial purposes not reasonably related to the conduct of its business unless the cable or video provider has provided to the customer a notice, separately or included in any other customer service notice, that clearly and conspicuously describes the customer's ability to prohibit the disclosure. Cable or video providers shall provide an address and telephone number for a customer to use without a toll charge to prevent disclosure of the customer's name and address in mailing lists or for other commercial purposes not reasonably related to the conduct of its business to other businesses or affiliates of the cable or video provider. Cable or video providers shall comply with the consumer privacy requirements of Section 26-4.5 of the Criminal Code of 2012, the Restricted Call Registry Act, and 47 U.S.C. 551 that are in effect as of June 30, 2007 (the effective date of Public Act 95-9) and as amended thereafter.

(q) Cable or video providers shall implement an informal process for handling inquiries from local units of government and customers concerning billing issues, service issues, privacy concerns, and other consumer complaints. In the event that an issue is not resolved through this informal process, a local unit of government or the customer may request nonbinding mediation with the cable or video provider, with each party to bear its own costs of such mediation. Selection of the mediator will be by mutual agreement, and preference will be given to mediation services that do not charge the consumer for their services. In the event that the informal process does not produce a satisfactory result to the customer or the local unit of government, enforcement may be pursued as provided in subdivision (4) of subsection (r) of this Section.

(r) The Attorney General and the local unit of government may enforce all of the customer service and privacy protection standards of this Section with respect to complaints received from residents within the local unit of government's jurisdiction, but it may not adopt or seek to enforce any additional or different customer service or performance standards under any other authority or provision of law.

(1) The local unit of government may, by ordinance, provide a schedule of penalties for any material breach of this Section by cable or video providers in addition to the penalties provided herein. No monetary penalties shall be assessed for a material breach if it is out of the reasonable control of the cable or video providers or its affiliate. Monetary penalties adopted in an ordinance pursuant to this Section shall apply on a competitively neutral basis to all providers of cable service or video service within the local unit of government's jurisdiction. In no event shall the penalties imposed under this subsection (r) exceed $750 for each day of the material breach, and these penalties shall not exceed $25,000 for each occurrence of a material breach per customer.

(2) For purposes of this Section, "material breach" means any substantial failure of a cable or video service provider to comply with service quality and other standards specified in any provision of this Act. The Attorney General or the local unit of government shall give the cable or video provider written notice of any alleged material breaches of this Act and allow such provider at least 30 days from receipt of the notice to remedy the specified material breach.

(3) A material breach, for the purposes of assessing penalties, shall be deemed to have occurred for each day that a material breach has not been remedied by the cable service or video service provider after the expiration of the period specified in subdivision (2) of this subsection (r) in each local unit of government's jurisdiction, irrespective of the number of customers affected.

(4) Any customer, the Attorney General, or a local unit of government may pursue alleged violations of this Act by the cable or video provider in a court of competent jurisdiction. A cable or video provider may seek judicial review of a decision of a local unit of government imposing penalties in a court of competent jurisdiction. No local unit of government shall be subject to suit for damages or other relief based upon its action in connection with its enforcement or review of any of the terms, conditions, and rights contained in this Act except a court may require the return of any penalty it finds was not properly assessed or imposed.

(s) Cable or video providers shall credit customers for violations in the amounts stated herein. The credits shall be applied on the statement issued to the customer for the next monthly billing cycle following the violation or following the discovery of the violation. Cable or video providers are responsible for providing the credits described herein and the customer is under no obligation to request the credit. If the customer is no longer taking service from the cable or video provider, the credit amount will be refunded to the customer by check within 30 days of the termination of service. A local unit of government may, by ordinance, adopt a schedule of credits payable directly to customers for breach of the customer service standards and obligations contained in this Article, provided the schedule of customer credits applies on a competitively neutral basis to all providers of cable service or video service in the local unit of government's jurisdiction and the credits are not greater than the credits provided in this Section.

(1) Failure to keep an appointment or to notify the customer prior to the close of business on the business day prior to the scheduled appointment: $25.00.

(2) Violation of customer service and billing standards in subsections (c) and (d) of this Section: $25.00 per occurrence.

(3) Violation of the bundling rules in subsection (h) of this Section: $25.00 per month.

(t) The enforcement powers granted to the Attorney General in Article XXI of this Act shall apply to this Article, except that the Attorney General may not seek penalties for violation of this Article other than in the amounts specified herein. Nothing in this Section shall limit or affect the powers of the Attorney General to enforce the provisions of Article XXI of this Act or the Consumer Fraud and Deceptive Business Practices Act.

(u) This Article applies to all cable and video providers in the State, including but not limited to those operating under a local franchise as that term is used in 47 U.S.C. 522(9), those operating under authorization pursuant to Section 11-42-11 of the Illinois Municipal Code, those operating under authorization pursuant to Section 5-1095 of the Counties Code, and those operating under a State-issued authorization pursuant to Article XXI of this Act.

(Source: P.A. 97-1108, eff. 1-1-13; 97-1150, eff. 1-25-13; 98-45, eff. 6-28-13.)

(220 ILCS 5/22-502)

Sec. 22-502. The provisions of this Article are a limitation of home rule powers under subsection (h) of Section 6 of Article VII of the Illinois Constitution.

(Source: P.A. 95-9, eff. 6-30-07; 95-876, eff. 8-21-08.)

(220 ILCS 5/22-503)

Sec. 22-503. The provisions of this Article are severable under Section 1.31 of the Statute on Statutes.

(Source: P.A. 95-9, eff. 6-30-07; 95-876, eff. 8-21-08.)

(220 ILCS 5/Art. 70 heading) ARTICLE 70. (RENUMBERED) (Source: P.A. 95-9, eff. 6-30-07; renumbered by P.A. 95-876, eff. 8-21-08.)