HB2172 103RD GENERAL ASSEMBLY

LRB103 28925 AMQ 55311 b

103RD GENERAL ASSEMBLY
State of Illinois
2023 and 2024
HB2172

Introduced 2/7/2023, by Rep. William "Will" Davis

SYNOPSIS AS INTRODUCED:

See Index

Amends the Public Utilities Act. Provides that the utilities shall implement energy efficiency measures targeted at low-income households and the amount of expenditures in the utilities' annual energy efficiency program budget to implement these targeted measures shall be, at a minimum, proportional to the percentage of low-income customers within the utilities' service territory. Provides specified requirements for who qualifies as a low-income customer. Provides that a utility shall not disconnect service of: (1) low-income customers 65 years of age or older due to inability to afford the monthly bill; (2) low-income customers with children in the household under the age of 6 due to inability to afford the monthly bill; and (3) customers who have provided a medical certification exemption. Provides that if gas or electricity is used as the only source of space cooling, then a utility with over 100,000 residential customers may not terminate gas or electric utility service to the residential user, including all tenants of mastermetered apartment buildings: (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 or heat index will be 85 (rather than 95) degrees Fahrenheit or above; or (2) on any day preceding or during a holiday or weekend when a forecast indicates that the temperature or heat index will be 85 (rather than 95) degrees Fahrenheit or above during the holiday or weekend. Makes changes to provisions concerning: the Commission's annual report; notice of termination of service; utility credit reporting; consideration of attorney and expert compensation as an expense and intervenor compensation fund; prohibition against preference or prejudice to any corporation; proceedings, investigations, or hearings conducted by the Commission; complaints and notice; and automatic adjustment clause tariffs. Makes other and corresponding changes.

A BILL FOR

AN ACT concerning regulation.

Be it enacted by the People of the State of Illinois, represented in the General Assembly:

Section 5. The Public Utilities Act is amended by changing Sections 1-102, 4-201, 4-304, 8-101.5, 8-103B, 8-104, 8-201, 8-201.10, 8-202, 8-205, 8-206, 8-207, 8-209, 9-229, 9-241, 10-103, 10-108, 10-111, 16-111.8, and 19-145 and by adding Sections 3-127, 8-201.11, 8-202.5, 8-202.6, 8-202.7, 8-202.8, and 8-207.5 as follows:

(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 customers citizens require the provision of adequate, efficient, reliable, affordable, 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 customers 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, affordable energy services at the least possible cost to the customers 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 consistent 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) (blank) 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 customers; and citizens.

(ix) no utility policy or rate disproportionately impacts the availability of essential utility service to particular communities, as highlighted by data, including, but not limited to, monthly credit and collections data filed by a utility under Section 8-201.10.

(e) Affordability: the ability of utilities to ensure uninterrupted access to essential utility service and minimize disconnections to residential customers in such manner that ensures:

(i) all low-income customers, defined as those whose income falls at or below 80 percent of area median income, have access to a discounted utility rate;

(ii) low-income customers 65 years of age or older are not disconnected from essential utility service due to inability to afford the monthly bill;

(iii) low-income customers with children under the age of 6 are not disconnected from essential utility service due to inability to afford the monthly bill;

(iv) persons with medical conditions that a medical or qualified professional as described in subsection (b) of Section 8-202.7 certifies that an existing health condition will be exacerbated by disconnection from essential utility service are not disconnected from essential utility service;

(v) disconnection of essential utility service is not accelerated based on a utility's payment risk assessment of a customer; and

(vi) a utility assesses whether a customer may be eligible for energy assistance programs under the Energy Assistance Act, provides said customer with specific information as to where and how to obtain energy assistance, and ceases disconnection activity for 60 days to allow the customer to apply for and establish eligibility for said energy assistance. An utility shall not disconnect any customer who is in the process of apply for energy assistance as provided for under the Energy Assistance Act while the customer's application for energy assistance is pending if the utility has been notified by a community action agency that the customer has a pending application.

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 5/3-127 new)

Sec. 3-127. Low-income customer. "Low-income customer" means an income-qualified residential customer whose income falls at or below 80% of the area median income.

(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 and the public utilities under its jurisdiction to provide detailed, accessible, and adequate information to the public on the availability of financial assistance customers struggling to afford essential utility service and the rights and remedies available to utility customers with the goal of ensuring affordability of utility rates and access to uninterrupted essential utility service. The Commission shall report annually to the General Assembly on the impact of its rulings on the rates of utility customers, including general rate increases granted, rider surcharges assessed by the utilities, and how it ensured that certain communities or customers were not disproportionately impacted by utility rate and policies in terms of equity, affordability, and environmental impact, consistent with its obligations under Section 4-304. The Commission shall conduct quarterly public meetings in the evening with a minimum of 3 commissioners in attendance that permit members of the public to communicate issues of concern regarding utility rates and policies. Two of the quarterly meetings shall take place in the central and southern part of this 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.

It shall be the duty of the Commission to assemble and maintain a staff consisting of experts in computer systems, public policy, consumer advocacy, accounting, engineering, and other professional disciplines necessary to ensure the equitable regulation of public utility rates, policies, and other utility obligations created under this Act.

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

Sec. 4-304.

(a) 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 on customers and low-income customers in particular, 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, accessible on an uninterrupted basis, and consistently reliable to all Illinois customers 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.

(d) an analysis of the financial impact on low-income customer affordability of rate changes and low-income customers' access, as compared with other residential customers, to all existing and proposed utility programs and services associated with energy market transition, energy efficiency, implementation of renewable energy, clean energy and transportation programming, and all rates created pursuant to Public Act 102-662. Such assessment shall also include said costs associated with utility research and development and utility deferred maintenance.

As part of this report on the availability of essential utility service, the Commission's report shall contain the following information:

(1) A plain language summary of the data reported by public utilities pursuant to Section 8-201.10 for the reporting year, including any significant trends or changes concerning customer assistance programs, service disconnections, and debt collection.

(2) The Commission's assessment of the impact of customer assistance programs, service disconnection policies, and collections policies on the affordability and accessibility of utility service, including whether certain customer segments, by zip code, census tract, income level, and racial group are disproportionately impacted by a public utility's disconnections and collections policies.

(3) The Commission's assessment of whether additional data reporting is needed to understand and address issues related to the affordability and accessibility of utility service.

(4) The Commission's assessment of whether the data reported by public utilities pursuant to Section 8-201.10 indicates the existence of a significant issue disparity impacting the public health, safety, or welfare of particular communities that requires further investigation and remedy by the Commission or other public officials.

(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, discount rate tariff and related program evaluations and 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.

(10) A description of all household engagement education, both written and in-person, about utility regulation, opportunities to participate in Commission proceedings and open meetings, and how to access energy assistance and low-income discount rates the Commission has completed for the year.

(11) A summary of the annual reports filed by the utilities pursuant to Section 5-109 that incorporates information, including, but not limited to, overall rate increases that have occurred during the year, amounts recovered through individual rider surcharge tariffs, utility net operating income, earned return on equity levels, uncollectibles levels, and pending arrearage levels.

(12) For all federal and State grants, incentives, low-cost loans for which the utility has or will apply for in the coming year, in particular under the Infrastructure Investment and Jobs Act, Inflation Reduction Act of 2022, and Justice40 Initiative, utilities shall report on the details of the projects and partnerships proposed, the geographies impacted, and any likely impact on customer rates and bills.

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.

(b) The Commission shall, within 30 days of the effective date of this amendatory Act of the 103rd General Assembly, open a proceeding that analyzes, by zip code and census tract, the reporting by public utilities of historical data concerning customer assistance programs, service disconnections, and debt collection, including: the number of customers enrolled in customer assistance programs; the number of service disconnections; the number of service reconnections; the duration of customer disconnections; the number of customers in arrears and the total dollar amount owed and the average amount owed by those customers; and such other information as the Commission deems appropriate to promote the public health, safety, and welfare. The Commission shall make findings and conclusions in an order, with specific direction to utilities on changes in utility practices needed to ensure the affordability of rates and uninterrupted access to essential utility service for financially struggling customers to the maximum extent possible and consistent with the Act.

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

(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, accelerate disconnection, 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 5/8-103B)

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 Btu's 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 subjection (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, 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 the amount of expenditures in the utilities' annual energy efficiency program budget to implement these targeted the measures shall be, at a minimum, proportional to the percentage of low-income customers within the utilities' service territory 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. Admin. 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 paragraphs (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) this amendatory Act of the 102nd General Assembly, 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. 101-81, eff. 7-12-19; 102-662, eff. 9-15-21; revised 2-28-22.)

(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, 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, 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. Notwithstanding this requirement, 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 the amount of expenditures in the utilities' annual energy efficiency program budget to implement these targeted measures shall be, at a minimum, proportional to the percentage of low-income customers within the utilities' service territory.

(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. 98-90, eff. 7-15-13; 98-225, eff. 8-9-13; 98-604, eff. 12-17-13; 99-906, eff. 6-1-17.)

(220 ILCS 5/8-201) (from Ch. 111 2/3, par. 8-201)

Sec. 8-201.

(a) 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 prospective and existing residential heating customers deal with each other in good faith and fair manner.

(b) It is further the policy of this State that public utilities shall treat qualifying low-income prospective or existing customers in good faith and in a fair manner to protect the customers' access to essential utility service, to set deferred payment arrangements for past due amounts that are affordable and which shall be based on the customer's ability to make payments on the past due balance while paying current bills, and to maximize the opportunity to use essential utility service without interruption or disconnection.

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

(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.

(d) The Commission shall, within 30 days of the effective date of this amendatory Act of the 103rd General Assembly, open a proceeding that analyzes, by zip code and census tract, the reporting by public utilities of historical data concerning customer assistance programs, service disconnections, and debt collection, including: the number of customers enrolled in customer assistance programs; the number of service disconnections; the number of service reconnections; the duration of customer disconnections; the number of customers in arrears and the total dollar amount owed and the average amount owed by those customers; and such other information as the Commission deems appropriate to promote the public health, safety, and welfare. The Commission shall make findings and conclusions in an order, with specific direction to utilities on changes in utility practices needed to ensure the affordability of rates and uninterrupted access to essential utility service for financially struggling customers to the maximum extent possible and consistent with the Act.

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

(220 ILCS 5/8-201.11 new)

Sec. 8-201.11. Qualified low-income customer.

(a) Within 60 days after the effective date of this amendatory act of the 103rd General Assembly, public utilities shall treat a prospective or existing residential customer that participates in the programs identified in subsection (b) as a qualified low-income customer for purposes of this Act. All rules implemented under this Act shall use the definition of qualified low-income customer contained in this Section and include additional criteria only if the additional criteria expand a customer's eligibility for services as a qualified low-income customer.

(b) For purposes of this Act and the rules adopted to implement this Act, a qualified low-income customers is a prospective or existing customer who:

(1) is a parent or guardian of a child enrolled in Head Start or who is eligible to receive free or reduced-price lunches or breakfasts under the federal Child Nutrition Act of 1966 and under the National School Lunch Act;

(2) has received grant assistance for medical services within the last 12 months;

(3) participates in or receives benefits pursuant to one or more of the following programs:

(A) the Women, Infants and Children Nutrition Program;

(B) the Supplemental Nutrition Assistance Program;

(C) the Low-Income Home Energy Assistance Program;

(D) the Percentage of Income Payment Plan Program;

(E) the Federal Temporary Assistance for Needy Families;

(F) the Rental Housing Support Program;

(G) the Housing Choice Voucher Program under Section 8 of the United States Housing Act of 1937;

(H) supplemental security income;

(I) Medicaid;

(J) the federal lifeline service;

(K) dependency and indemnity compensation for a surviving spouse or parents of a veteran; or

(L) Social Security disability insurance; or

(4) can demonstrate income at or below 80% of area median income guidelines.

(c) To the extent that a public utility cannot obtain electronic verification of a prospective or existing customer's participation in the programs identified in subsection (b) or of low-income status from State or federal agencies, a public utility shall accept, in either paper or electronic format, any of the following documentation as proof that a customer participates in or receives benefits pursuant to one or more of the qualifying programs:

(1) a current or prior year's statement of benefits from a qualifying program or a notice or letter of participation in a qualifying program;

(2) program participation documents, or other official documents, demonstrating that the customer, the customer's dependents, or the customer's household receives benefits from a qualifying program;

(3) the prior year's State, federal, or tribal tax return;

(4) a current income statement from an employer or a paycheck stub;

(5) a Social Security statement of benefits;

(6) a federal Veterans Affairs statement of benefits;

(7) a retirement or pension statement of benefits;

(8) an unemployment or workers' compensation statement of benefits;

(9) a federal or tribal notice letter of participation in general assistance from the federal Temporary Assistance for Needy Families; or

(10) a divorce decree, child support award, or other official document containing income information.

(d) A public utility may communicate with State and federal benefits agencies and with qualified community-based organizations, such as community action agencies, public housing authorities, or community development corporations, to verify that a prospective or existing customer is a qualified low-income customer and may utilize electronic and information technology to verify that a prospective or existing customer is a qualified low-income customer in place of documentation provided by the customer.

(e) A public utility shall verify a customer as a qualified low-income customer as soon as practicable. A public utility shall not disconnect a customer's utility service or engage in any other collection activities during the verification process.

(f) Notwithstanding any other provision of this Act, nothing in this Section shall prohibit a utility from accepting a customer's self-certification that the customer qualifies for low-income customer status for the purpose of establishing eligibility for programs and protections identified in this Act. A utility shall not be obligated to conduct an independent authentication of the documentation provided by the prospective or existing customer pursuant to subsection (c). A utility shall not be held liable if the documentation provided by the prospective or existing customer is determined to be fraudulent.

(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, in every case in which service may be terminated or cut off due to nonpayment and to any residential customer 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.

Such notice shall include a prominent notice, within 60 days of the effective date of this amendatory act of the 103rd General Assembly, substantially in the same form provided in Section 8-202.6, stating that customers may be entitled to accommodations as required by law to preserve service, including the availability of deferred payment arrangements and the option to be treated as a qualified low-income customer, pursuant to Section 8-201.7 and shall be sent by U.S. Mail at least 14 days prior to termination of service or supply or delivered by other means to the customer 7 days prior to such termination.

Additionally, consistent with paragraph (1) of subsection (b) of Section 2 of the Energy Assistance Act, the utility shall:

(i) demonstrate efforts to notify and advise the customer of weatherization and energy efficiency services to treat the customers' homes and thereby reduce the customers' bill;

(ii) provide the customer with information about accessing any available financial assistance or other resources to help reduce the customers' existing arrearages and monthly utility bill;

(iii) notify the customer of options for leveling the customers' bill; and

(iv) provide adequate and accessible written notice in the appropriate language 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.

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 consistent with this Act.

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 5/8-202.5 new)

Sec. 8-202.5. Deferred payment arrangements.

(a) If a prospective or existing customer of a public utility has past due arrearages, the public utility may provide the customer a prominent notice, substantially in the same form provided in Section 8-202.6, stating that the customer may be entitled to accommodation as required by law to pay the amounts past due and to preserve utility service, including the availability of deferred payment arrangements and the option to be treated as a qualified low-income customer pursuant to Section 8-201.11. Notice shall be sent by U.S. Mail. In addition to the written notice, if a prospective or existing customer contacts the utility about a past due bill or inability to pay, the utility shall notify the customer of the option to become a qualified low-income customer pursuant to Section 8-201.11.

(b) The utility shall offer a deferred payment arrangement to any prospective or existing residential customer who has a past due amount for utility service to retire the debt. Every deferred payment arrangement shall be determined by both the utility and the customer receiving residential utility service and shall be designed to reflect each customer's particular financial circumstances. The utility has an affirmative obligation to take into account the customer's ability to successfully complete the deferred payment arrangement, which shall be based on the customer's ability to make payments on the past due balance while paying current bills. The customer shall have the option, when negotiating a deferred payment arrangement, to include the current month's bill in the total amount to be paid over the term of the deferred payment arrangement.

(c) The utility shall offer to a prospective or existing customer who is a qualified low-income customer pursuant to Section 8-201.11 a deferred payment arrangement with no down payment, installments as low as $10 per month, and the option to enter into a levelized payment plan for the payment of future bills, or up to 36 months in length, whichever is longer. If the customer is not eligible to be a qualified low-income customer, the utility shall not require the customer to pay as a down payment more than the lesser of $100 or 10% of the total outstanding bill, unless the customer expressly offers to pay a larger down payment. The amount of time negotiated with the customer for the completion of the deferred payment agreement shall take into account the ability of the customer to successfully complete the deferred payment arrangement. The term of the deferred payment arrangement shall be no less than 12 months, unless the customer expressly agrees to a shorter term.

(d) The public utility shall not require a deposit or charge a fee for entering into, renegotiating, or reinstating a deferred payment arrangement or charge any interest or late payment charge on deferred payment plan balances or payments or for reconnecting utility service after disconnection.

(e) As a part of establishing a deferred payment arrangement, the public utility shall have an affirmative obligation to

(1) check a customer's eligibility for qualified low income status;

(2) determine if weatherization or energy efficiency services were offered to the customer eligible for such services and direct the customer to a telephone number and website at which the customer can request said services;

(3) offer information about grants or other available bill and arrearage payment supports, including programs offered under the Energy Assistance Act; and

(4) offer the customer the opportunity to evaluate the effectiveness of a levelized bill.

(f) No later than 10 business days after the utility and the customer have reached a mutually agreeable deferred payment arrangement, the utility shall provide a written statement to the customer that includes the terms of the deferred payment arrangement, including: (i) the date the payment is due; (ii) the amount of the down payment, if any; (iii) the amount of the monthly installment; (iv) the length of the deferred payment arrangement, in months; and (v) the date the final payment is due.

(g) A qualified low-income customer who has failed to complete a previous deferred payment arrangement shall be entitled to enter into a new or renegotiated deferred payment arrangement. The amount of time negotiated with the customer for the completion of a new deferred payment agreement shall take into account the ability of the customer's financial circumstances and to successfully complete the deferred payment arrangement, notwithstanding the terms of any earlier agreement.

(h) A customer whose financial circumstances change during the course of a deferred payment agreement shall be allowed to renegotiate the installment amounts and length of the deferred payment arrangement with the utility in accordance with this Section to ensure the successful completion of the deferred payment arrangement. The amount of time negotiated with the customer for the completion of the deferred payment agreement shall take into account the ability of the customer's financial circumstances and to successfully complete the deferred payment arrangement, notwithstanding any earlier agreement.

(i) No public utility shall require a deposit from a prospective or existing customer to obtain or continue service or as a condition of a deferred payment arrangement.

(j) Each public utility shall develop written procedures for evaluating the financial need of a customer or applicant, to be reviewed by the Commission for ensuring the confidential handling of such information, for arriving at fair and reasonable payment terms consistent with this Section, and for training its personnel. Such plans, including customer service representative scripts to be used by the utilities in providing these requirements, shall be filed with the Office of the Attorney General and the Commission. The Commission shall have a duty to develop guidelines for the utilities' development of written procedures.

(220 ILCS 5/8-202.6 new)

Sec. 8-202.6. Required notice to residential customers.

(a) Within 60 days of the effective date of this amendatory Act of the 103rd General Assembly, every public utility shall include the notice specified in subsection (b) at least twice every year to every residential customer and shall include the notice specified in subsection (b) in every bill with an amount past due and in every notice of disconnection. The Commission shall ensure that its rules and all notices required in its rules reflect the provisions of this amendatory Act of the l03rd General Assembly. The notice specified in subsection (b) is in addition to other customer notices required by the Commission.

(b) The notice required in subsection (a) shall be substantially in the following form, in at least 12-point font:

"IF YOU CANNOT PAY YOUR ENTIRE BILL NOW OR ARE FACING DISCONNECTION, SEE IMPORTANT PROTECTIONS BELOW:

All residential customers are eligible for certain protections to maintain their utility service. If you have amounts past due or are in danger of disconnection, your utility must first (i) check your eligibility for low-income customer status to see if you qualify for certain protections and rights under the Act; (ii) provide specific information about financial assistance programs offered by the utility and that are available under the Energy Assistance Act; (iii) provide information about accessing energy efficiency programs offered by the State and the utility, including weatherization services; and (iv) provide the opportunity for new bill payment due dates, levelized billing, and a deferred payment arrangement pursuant to Section 202.5 of the Public Utilities Act. The utility cannot discontinue your service unless it has offered you a deferred payment arrangement that is designed to reflect your specific financial circumstances. The utility cannot charge you a deposit to maintain your utility service and cannot charge a fee, interest, or late payment fee or charge for entering into or renegotiating a plan to repay your past due balance.

If you participate in or receive benefits from one of the programs listed below, you may be eligible for financial assistance and are eligible for a deferred payment arrangement with no down payment, installments as low as $10 per month, no less than 12 months to pay off the past due balance, and the option to enter into a levelized payment plan (budget billing) for the payment of future bills.

If you do not qualify as a low-income customer, the utility shall not require you to make a down payment of more than the lesser of $100 or 10% of the total outstanding bill and no less than 12 months to pay off the past due balance unless you expressly agree to pay a larger down payment or agree to a shorter term. You may also enter into a levelized payment plan (budget billing) for the payment of future bills.

You are a qualified low-income customer if you or a household member participate in or receive benefits from one of the following programs:

(1) Women, Infants and Children Nutrition Program (WIC);

(2) Supplemental Nutrition Assistance Program (SNAP);

(3) A free school breakfast and lunch program;

(4) Head Start;

(5) Low-Income Home Energy Assistance Program (LIHEAP);

(6) Percentage of Income Payment Plan (PIPP);

(7) Temporary Assistance for Needy Families (TANF);

(8) Illinois Housing Development Authority's Rental Housing Support Program;

(9) Federal public housing assistance (Section 8);

(10) Supplemental Security Income (SSI);

(11) Medicaid;

(12) Federal telephone lifeline service; or

(13) Dependency and Indemnity Compensation (DIC) for a surviving spouse or parents of a veteran.

You are also a qualified low-income customer if you:

(1) have received grant assistance for medical services within the last 12 months; or

(2) can demonstrate income at or below 80% of area median income."

(220 ILCS 5/8-202.7 new)

Sec. 8-202.7. Medical certification; prohibition on disconnection.

(a) A utility shall not disconnect service to a residence upon receipt of a valid medical certificate for a resident of a customer household for the duration of the medical condition in cases of certified medical necessity and provide an opportunity for the customer to retire past due amounts by periodic installments under an automatic medical payment arrangement commencing after 30 days.

(b) Certification may be made by either a licensed physician, nurse practitioner, physician assistant, psychiatrist, psychologist, social services representative, law enforcement official, or a local board of health.

(c) A utility shall certify a medical certificate protection from disconnection, initially, by phone call, and then through written notification provided within 10 days after an initial certification by phone call. A utility shall not reject any certification complying with the requirements provided in this subsection and subsection (b). A utility seeking to challenge a submitted medical certificate shall file a petition with the Commission that states the reasons why the certificate should be invalidated. The burden of proving a challenge to the validity of the medical certificate shall be on the utility with service of the petition provided to the certificated customer. Notice and an opportunity to appear before the Commission shall be provided to the customer referenced in the utility petition. The Commission may establish rules consistent with these provisions. When a valid medical certification is provided to the utility up to 14 days after disconnection, service shall be restored within one day after the provision of certification.

The utility shall not treat the disconnected customer as an applicant for service for purposes of restoration under a medical certificate.

(d) The certificate shall protect the account from disconnection for 60 days after the date of certification and may be renewed every 6 months for the duration of the medical condition referenced in the certification. If the customer was disconnected prior to certification, the 60 day period shall not begin until the utility restores the customer's service.

(e) A utility shall notify customers of the serious illness protection rules when a customer starts service, annually thereafter, in all collection and disconnection notices and communications, including telephone communications by utility customer service representatives with customers and in any post-disconnection communications, in both English and any other language used by substantial numbers of the utility's customers, consistent with the second language requirements provided in the Commission's rules. A utility shall act affirmatively to identify medically vulnerable customers and avoid terminating the customers' service. A utility shall, at the time of a customer's application and annually by mailing a preaddressed, postage-paid postcard, ask the new and existing customer to identify if the household includes a resident who is 65 or older, has children under the age of 6 in the household, or a disability or an emergency medical problem. The utility shall solicit customers quarterly to determine the presence of any life-sustaining equipment in the household.

(220 ILCS 5/8-202.8 new)

Sec. 8-202.8. Prohibition on disconnection of medically vulnerable customers due to financial inability to pay. Notwithstanding any other provision of this Act, a public utility shall not disconnect the service of:

(1) low-income customers 65 years of age or older due to inability to afford the monthly bill;

(2) low-income customers with children in the household under the age of 6 due to inability to afford the monthly bill; and

(3) customers who have provided a medical certification exemption consistent with Section 8-202.7.

(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 with over 100,000 residential customers may not terminate gas or electric utility service to the residential user, including all tenants of mastermetered apartment buildings:

(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 or heat index will be 85 95 degrees Fahrenheit or above; or

(2) on any day preceding or during a holiday or weekend when a forecast indicates that the temperature or heat index will be 85 95 degrees Fahrenheit or above during the holiday or weekend.

(Source: P.A. 95-772, eff. 8-1-08.)

(220 ILCS 5/8-206) (from Ch. 111 2/3, par. 8-206)

Sec. 8-206. Winter prohibition on 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. Customers with arrearages prior to December 1 shall be assessed for eligibility as qualified low-income customers, advised about weatherization and energy efficiency services, educated about the option of a levelized bill, and offered a deferred payment arrangement in accordance with Section 8-202.5. , 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) (Blank). 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) (Blank). 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. A residential customer shall also be offered the opportunity to renegotiate a deferred payment arrangement in accordance with Section 8-202.5 to avoid termination of service.

(e) (Blank). 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) (Blank). 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) (Blank). 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 or is a qualified low-income customer 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 5/8-207) (from Ch. 111 2/3, par. 8-207)

Sec. 8-207. Former residential customer.

(a) 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 unlawfully 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 immediate reconnection and a deferred payment arrangement under the provisions of Section 8-202.5. 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.

(b) 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 5/8-207.5 new)

Sec. 8-207.5. Smart meter reconnection. A public utility shall not charge a residential reconnection charge to a customer who receives service through a smart meter.

(220 ILCS 5/8-209)

Sec. 8-209. Utility credit reporting. A public utility shall not report a customer to a credit reporting agency for non-payment or late payment of an outstanding utility bill. 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 5/9-229)

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. Expenses related to travel or meals shall not be compensable through a utility's rates.

(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 of 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, equity, affordability, access, safety, or other policies matters affecting the pricing, rates, costs, charges, or other policies charges associated with utility service, the Commission considers and makes findings on an issue raised by a consumer interest representative adopts a material recommendation related to a significant issue in the docket, and participation caused the consumer interest representative to incur a significant expenses 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 the effective date of this amendatory Act of the 102nd General Assembly, 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 $1,000,000 $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 the effective date of this amendatory Act of the 102nd General Assembly. 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 the effective date of this amendatory Act of the 102nd General Assembly. 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 the effective date of this amendatory Act of the 102nd General Assembly. 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 the effective date of this amendatory Act of the 102nd General Assembly. 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 the effective date of this amendatory Act of the 102nd General Assembly. 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 the effective date of this amendatory Act of the 102nd General Assembly. 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. When funding in the Consumer Intervenor Compensation Fund is exhausted or insufficient to cover the reasonable expenses of a consumer interest representative in a proceeding, then the aforementioned utilities shall contribute the identical funding amounts provided for under paragraph (5) to replenish the Fund.

(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 the consumer interest representative to incur significant costs 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 through the utility's rates.

(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 considered and made a finding on an issue raised by a consumer interest representative to incur significant expense adopted a material recommendation related to a significant issue in the docket, and whether participation caused the consumer Interest representative to incur significant expense, 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.)

(220 ILCS 5/9-241) (from Ch. 111 2/3, par. 9-241)

Sec. 9-241. No public utility shall, as to rates or other charges, services, facilities or in other respect, including disconnection and other credit and collection policies, make or grant any preference or advantage to any corporation or person or subject any corporation or person to any prejudice or disadvantage. This prohibition does not include differentiations in rates or policies due to qualified low-income status as defined in Section 8-201.11. 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.

However, 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 creates 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.

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.

Following the completion of the discount rate study, the Commission shall require that electric and gas utilities propose low-income discount rates and associated notice requirements for customers whose income falls at or below 80% of area median income and file tariffs to reflect said discounts with the discounts tiered and decreased as income increases. The Commission shall review and by order approve, or approve as modified, the proposed tariff within 11 months after the date on which it is filed or within the statutory timeline required by the relevant utility filing.

In its review of the tariffs, the Commission shall ensure recovery of any cost associated with the tariffs be reflected in the rates charged to all customer classes. The tariff may be established outside the context of a general rate case filing, during which time the Commission shall specify the terms of an audit of the relevant utility practices, programs, and accounts associated with the delivery of services to low-income customers. Utility discount rate tariffs shall apportion the discount to the entire bill, including fixed charges and taxes.

Eligibility for the low-income discount rates described in this subsection may be established upon verification of a low-income customer's receipt of any means tested public benefit, consistent with Section 8-201.11, for verification of eligibility for the low-income home energy assistance program. The Department of Commerce and Economic Opportunity may enter into such contracts and other agreements with local agencies and utilities as may be necessary for the purpose of establishing eligibility for discount rates so that access to a specific tiered discount may be established through application for energy assistance under the Energy Assistance Act through a community action agency as a part of application for energy assistance.

The Department of Human Services shall make available to utilities the eligibility guidelines for said public benefit programs. Utilities shall establish an automated program of matching customer accounts with lists of recipients of said means tested public benefit programs, consistent with the appropriate customer privacy and confidentiality protections developed by the Commission under this Act. Based on the results of said matching program, utilities shall automatically enroll and presumptively provide a low-income discount rate to eligible customers so identified, subject to further income delineation relative to tiers in a utility's discount rate tariff. However, the utility, within 60 days of said presumptive enrollment, informs any such low-income customer of the automatic enrollment and all rights and obligations of a customer under said program, including the right to provide further information relative to household income associated with the approved discount tiered rate, or withdraw from said program without penalty. The automatic enrollment shall be consistent with the appropriate customer privacy and confidentiality protections developed by the Commission under this Act. Each utility shall conduct substantial engagement efforts to make low-income discount rates available to eligible customers and shall report to the Commission, at least twice annually, as to its engagement activities and results.

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 the customers' their monthly utility bills, and send out such information semi-annually, unless otherwise provided by this Article.

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.)

(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 and the public comments recorded on the Commission's website and orally at the Commission's open meetings, 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 5/10-108) (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, not-for-profit or community-based organization, 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 5/10-111) (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, including conclusions and findings that explain how the Commission assessed the affordability of utility rates for low-income customers in any general rate increase or tariff filing that impacts utility rates, the evidence presented in the proceeding relied upon by the Commission to conclude that the rate or rates approved are affordable to low-income customers, and how public comments, both oral and written, were considered and incorporated in the Commission's conclusions and findings. 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 5/16-111.8)

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, and that the utility has demonstrated actions to ensure that its rates are affordable and disconnections have been minimized in order to preserve the availability of utility services to all customers, consistent with item (viii) of subsection (d) of Section 1-102. The Commission shall review the prudence and reasonableness of the utility's actions to pursue minimization and collection of uncollectibles and preserve the availability of utility services to all customers, which shall include, at a minimum, the 7 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) (blank); identifying customers with late payments;

(2) contacting the customers in an effort to obtain payment;

(3) providing financially struggling delinquent customers with information about opportunities to reduce the customers' bills through weatherization, energy efficiency, grants, energy assistance, levelized bills, and other possible bill-saving options, including payment plans and assistance programs, and how to reach agencies and community-based organizations in the communities that provide assistance;

(4) specific action to limit disconnections in zip code and census tract areas that would otherwise be disproportionately impacted by the utility's credit and collection policies, including achievement of affordability metrics established under Section 16-108.18 serving disconnection notices;

(5) community engagement in areas demonstrating higher than average arrearages to help inform customers about available assistance programs; implementing disconnections based on the level of uncollectibles; and

(6) providing shareholder-funded bill payment assistance funds; pursuing collection activities based on the level of uncollectibles.

(7) demonstrating that the bill payment assistance funds have aided in the reduction of disconnections; and

(8) the offering of a Commission-approved discount rate tariff, tiered by income level, for customers whose income falls at or below 80% of area median income or 300% federal poverty level, whichever is greater, coupled with an arrearage reduction program that eliminates customer arrearages in ratable proportion for each month that plan participants timely pay their utility bill.

(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 5/19-145)

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, and that the utility has demonstrated actions to ensure that its rates are affordable and disconnections have been minimized in order to preserve the availability of utility services to all customers, consistent with item (viii) of subsection (d) of Section 1-102. 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 7 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) (blank); identifying customers with late payments;

(2) contacting the customers in an effort to obtain payment;

(3) providing delinquent customers with information about opportunities to reduce the customers' bills through weatherization, energy efficiency, grants, financial aid, levelized bills, and other possible bill-saving possible options, including payment plans and assistance programs, and how to reach agencies and community-based organizations in the communities that provide assistance;;

(3.5) specific action to limit disconnections in zip code and census tracts areas that would otherwise be disproportionately impacted by the utility's credit and collection policies;

(4) community engagement in areas demonstrating higher than average arrearages to help inform customers about available assistance programs serving disconnection notices;

(5) providing shareholder-funded bill payment assistance funds; implementing disconnections based on the level of uncollectibles; and

(6) demonstrating that the bill payment assistance funds have aided in the reduction of disconnections; and pursuing collection activities based on the level of uncollectibles.

(7) the offering of a Commission-approved discount rate tariff, tiered by income level, for customers whose income falls at or below 80% of area median income or 300% federal poverty level, whichever is greater, coupled with an arrearage reduction program that eliminates customer arrearages in ratable proportion for each month that plan participants timely pay the participant's utility bill.

(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.)