Public Act 1066 103RD GENERAL ASSEMBLY

HB0587 Enrolled LRB103 04172 CPF 49178 b

Public Act 103-1066

AN ACT concerning regulation.

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

Section 1. Short title. This Act may be cited as the Electric Transmission Systems Construction Standards Act.

Section 5. Definitions. For the purposes of this Act:

"Commission" means the Illinois Commerce Commission.

"Construction contractor" means any entity responsible for the construction, installation, maintenance, or repair of electric transmission systems subject to this Act.

"Electric transmission systems" means an electrical transmission system designed and constructed with the capability of being safely and reliably energized at 69 kilovolts or more, including transmission lines, transmission towers, conductors, insulators, foundations, grounding systems, access roads, and all associated transmission facilities, including transmission substations. "Electric transmission systems" does not include projects located on the electric generating facility's side of the facility's point of interconnection.

"OSHA" means Occupational Safety and Health Administration.

"Utility" has the meaning given to that term in Section 3-105 of the Public Utilities Act.

Section 10. Policy. The State of Illinois adopts the following policies to ensure that electric transmission systems are constructed to the highest standards of safety, competency, and reliability:

(1) Mandate the use of qualified, properly trained employees on all electric transmission systems.

(2) Protect workers by ensuring fair compensation in accordance with the Prevailing Wage Act.

(3) Promote public safety through OSHA-certified safety training and adherence to apprenticeship standards.

Section 15. Requirements for contractors.

(a) Prevailing wage compliance. All utilities and construction contractors responsible for the construction, installation, maintenance, or repair of electric transmission systems shall pay employees performing the construction, installation, maintenance, or repair work of such systems wages and benefits consistent with the Prevailing Wage Act.

(b) Training and competence requirement. To ensure safety and reliability in the construction, installation, maintenance, and repair of electric transmission systems, each electric utility and construction contractor must demonstrate the competence of their employees who are performing the work of construction, installation, maintenance, or repair of electric transmission systems, which shall be consistent with the standards required by Illinois utilities as of January 1, 2007, or greater. Competence must include, at a minimum: (1) completion, or active participation with ultimate completion, in an accredited or recognized apprenticeship program for the relevant craft, trade, or skill; or (2) a minimum of 2 years of direct employment in the specific work function.

The Commission shall oversee compliance to ensure employees meet these standards.

(c) Safety training. All employees engaged in the construction, installation, maintenance, or repair of electric transmission systems must successfully complete OSHA-certified safety training required for their specific roles on the project site.

(d) Diversity Plan.

(1) All construction contractors engaged in the construction, installation, maintenance, or repair of electric transmission systems shall develop a Diversity Plan that sets forth:

(A) the goals for apprenticeship hours to be performed by minorities and women;

(B) the goals for total hours to be performed by underrepresented minorities and women; and

(C) spending for women-owned, minority-owned, veteran-owned, and small business enterprises in the previous calendar year.

(2) These goals shall be expressed as a percentage of the total work performed by the construction contractor submitting the plan and the actual spending for all women-owned, minority-owned, veteran-owned, and small business enterprises shall also be expressed as a percentage of the total work performed by the construction contractor submitting the Diversity Plan.

(3) For purposes of the Diversity Plan, minorities and women shall have the same definition as defined in the Business Enterprise for Minorities, Women, and Persons with Disabilities Act.

(4) The construction contractor shall submit the Diversity Plan to the Commission.

Section 20. Rulemaking authority. The Commission shall adopt rules to implement and enforce this Act, including investigation procedures, penalties, and reporting requirements.

Section 50. The Illinois Enterprise Zone Act is amended by changing Section 5.5 as follows:

(20 ILCS 655/5.5) (from Ch. 67 1/2, par. 609.1)

Sec. 5.5. High Impact Business.

(a) In order to respond to unique opportunities to assist in the encouragement, development, growth, and expansion of the private sector through large scale investment and development projects, the Department is authorized to receive and approve applications for the designation of "High Impact Businesses" in Illinois, for an initial term of 20 years with an option for renewal for a term not to exceed 20 years, subject to the following conditions:

(1) such applications may be submitted at any time during the year;

(2) such business is not located, at the time of designation, in an enterprise zone designated pursuant to this Act, except for grocery stores, as defined in the Grocery Initiative Act, and a new battery energy storage solution facility, as defined by subparagraph (I) of paragraph (3) of this subsection (a);

(3) the business intends to do, commits to do, or is one or more of the following:

(A) the business intends to make a minimum investment of $12,000,000 which will be placed in service in qualified property and intends to create 500 full-time equivalent jobs at a designated location in Illinois or intends to make a minimum investment of $30,000,000 which will be placed in service in qualified property and intends to retain 1,500 full-time retained jobs at a designated location in Illinois. The terms "placed in service" and "qualified property" have the same meanings as described in subsection (h) of Section 201 of the Illinois Income Tax Act; or

(B) the business intends to establish a new electric generating facility at a designated location in Illinois. "New electric generating facility", for purposes of this Section, means a newly constructed electric generation plant or a newly constructed generation capacity expansion at an existing electric generation plant, including the transmission lines and associated equipment that transfers electricity from points of supply to points of delivery, and for which such new foundation construction commenced not sooner than July 1, 2001. Such facility shall be designed to provide baseload electric generation and shall operate on a continuous basis throughout the year; and (i) shall have an aggregate rated generating capacity of at least 1,000 megawatts for all new units at one site if it uses natural gas as its primary fuel and foundation construction of the facility is commenced on or before December 31, 2004, or shall have an aggregate rated generating capacity of at least 400 megawatts for all new units at one site if it uses coal or gases derived from coal as its primary fuel and shall support the creation of at least 150 new Illinois coal mining jobs, or (ii) shall be funded through a federal Department of Energy grant before December 31, 2010 and shall support the creation of Illinois coal mining jobs, or (iii) shall use coal gasification or integrated gasification-combined cycle units that generate electricity or chemicals, or both, and shall support the creation of Illinois coal mining jobs. The term "placed in service" has the same meaning as described in subsection (h) of Section 201 of the Illinois Income Tax Act; or

(B-5) the business intends to establish a new gasification facility at a designated location in Illinois. As used in this Section, "new gasification facility" means a newly constructed coal gasification facility that generates chemical feedstocks or transportation fuels derived from coal (which may include, but are not limited to, methane, methanol, and nitrogen fertilizer), that supports the creation or retention of Illinois coal mining jobs, and that qualifies for financial assistance from the Department before December 31, 2010. A new gasification facility does not include a pilot project located within Jefferson County or within a county adjacent to Jefferson County for synthetic natural gas from coal; or

(C) the business intends to establish production operations at a new coal mine, re-establish production operations at a closed coal mine, or expand production at an existing coal mine at a designated location in Illinois not sooner than July 1, 2001; provided that the production operations result in the creation of 150 new Illinois coal mining jobs as described in subdivision (a)(3)(B) of this Section, and further provided that the coal extracted from such mine is utilized as the predominant source for a new electric generating facility. The term "placed in service" has the same meaning as described in subsection (h) of Section 201 of the Illinois Income Tax Act; or

(D) the business intends to construct new transmission facilities or upgrade existing transmission facilities at designated locations in Illinois, for which construction commenced not sooner than July 1, 2001. For the purposes of this Section, "transmission facilities" means transmission lines with a voltage rating of 115 kilovolts or above, including associated equipment, that transfer electricity from points of supply to points of delivery and that transmit a majority of the electricity generated by a new electric generating facility designated as a High Impact Business in accordance with this Section. The term "placed in service" has the same meaning as described in subsection (h) of Section 201 of the Illinois Income Tax Act; or

(E) the business intends to establish a new wind power facility at a designated location in Illinois. For purposes of this Section, "new wind power facility" means a newly constructed electric generation facility, a newly constructed expansion of an existing electric generation facility, or the replacement of an existing electric generation facility, including the demolition and removal of an electric generation facility irrespective of whether it will be replaced, placed in service or replaced on or after July 1, 2009, that generates electricity using wind energy devices, and such facility shall be deemed to include any permanent structures associated with the electric generation facility and all associated transmission lines, substations, and other equipment related to the generation of electricity from wind energy devices. For purposes of this Section, "wind energy device" means any device, with a nameplate capacity of at least 0.5 megawatts, that is used in the process of converting kinetic energy from the wind to generate electricity; or

(E-5) the business intends to establish a new utility-scale solar facility at a designated location in Illinois. For purposes of this Section, "new utility-scale solar power facility" means a newly constructed electric generation facility, or a newly constructed expansion of an existing electric generation facility, placed in service on or after July 1, 2021, that (i) generates electricity using photovoltaic cells and (ii) has a nameplate capacity that is greater than 5,000 kilowatts, and such facility shall be deemed to include all associated transmission lines, substations, energy storage facilities, and other equipment related to the generation and storage of electricity from photovoltaic cells; or

(F) the business commits to (i) make a minimum investment of $500,000,000, which will be placed in service in a qualified property, (ii) create 125 full-time equivalent jobs at a designated location in Illinois, (iii) establish a fertilizer plant at a designated location in Illinois that complies with the set-back standards as described in Table 1: Initial Isolation and Protective Action Distances in the 2012 Emergency Response Guidebook published by the United States Department of Transportation, (iv) pay a prevailing wage for employees at that location who are engaged in construction activities, and (v) secure an appropriate level of general liability insurance to protect against catastrophic failure of the fertilizer plant or any of its constituent systems; in addition, the business must agree to enter into a construction project labor agreement including provisions establishing wages, benefits, and other compensation for employees performing work under the project labor agreement at that location; for the purposes of this Section, "fertilizer plant" means a newly constructed or upgraded plant utilizing gas used in the production of anhydrous ammonia and downstream nitrogen fertilizer products for resale; for the purposes of this Section, "prevailing wage" means the hourly cash wages plus fringe benefits for training and apprenticeship programs approved by the U.S. Department of Labor, Bureau of Apprenticeship and Training, health and welfare, insurance, vacations and pensions paid generally, in the locality in which the work is being performed, to employees engaged in work of a similar character on public works; this paragraph (F) applies only to businesses that submit an application to the Department within 60 days after July 25, 2013 (the effective date of Public Act 98-109); or

(G) the business intends to establish a new cultured cell material food production facility at a designated location in Illinois. As used in this paragraph (G):

"Cultured cell material food production facility" means a facility (i) at which cultured animal cell food is developed using animal cell culture technology, (ii) at which production processes occur that include the establishment of cell lines and cell banks, manufacturing controls, and all components and inputs, and (iii) that complies with all existing registrations, inspections, licensing, and approvals from all applicable and participating State and federal food agencies, including the Department of Agriculture, the Department of Public Health, and the United States Food and Drug Administration, to ensure that all food production is safe and lawful under provisions of the Federal Food, Drug and Cosmetic Act related to the development, production, and storage of cultured animal cell food.

"New cultured cell material food production facility" means a newly constructed cultured cell material food production facility that is placed in service on or after June 7, 2023 (the effective date of Public Act 103-9) or a newly constructed expansion of an existing cultured cell material food production facility, in a controlled environment, when the improvements are placed in service on or after June 7, 2023 (the effective date of Public Act 103-9); or

(H) the business is an existing or planned grocery store, as that term is defined in Section 5 of the Grocery Initiative Act, and receives financial support under that Act within the 10 years before submitting its application under this Act; or and

(I) the business intends to establish a new battery energy storage solution facility at a designated location in Illinois. As used in this paragraph (I):

"New battery energy storage solution facility" means a newly constructed battery energy storage facility, a newly constructed expansion of an existing battery energy storage facility, or the replacement of an existing battery energy storage facility that stores electricity using battery devices and other means. "New battery energy storage solution facility" includes any permanent structures associated with the new battery energy storage facility and all associated transmission lines, substations, and other equipment that is related to the storage and transmission of electric power and that has a capacity of not less than 20 megawatt and storage capability of not less than 40 megawatt hours of energy; or

(J) the business intends to construct a new high voltage direct current converter station at a designated location in Illinois. As used in this paragraph, "high voltage direct current converter station" has the same meaning given to that term in Section 1-10 of the Illinois Power Act; and

(4) no later than 90 days after an application is submitted, the Department shall notify the applicant of the Department's determination of the qualification of the proposed High Impact Business under this Section.

(b) Businesses designated as High Impact Businesses pursuant to subdivision (a)(3)(A) of this Section shall qualify for the credits and exemptions described in the following Acts: Section 9-222 and Section 9-222.1A of the Public Utilities Act, subsection (h) of Section 201 of the Illinois Income Tax Act, and Section 1d of the Retailers' Occupation Tax Act; provided that these credits and exemptions described in these Acts shall not be authorized until the minimum investments set forth in subdivision (a)(3)(A) of this Section have been placed in service in qualified properties and, in the case of the exemptions described in the Public Utilities Act and Section 1d of the Retailers' Occupation Tax Act, the minimum full-time equivalent jobs or full-time retained jobs set forth in subdivision (a)(3)(A) of this Section have been created or retained. Businesses designated as High Impact Businesses under this Section shall also qualify for the exemption described in Section 5l of the Retailers' Occupation Tax Act. The credit provided in subsection (h) of Section 201 of the Illinois Income Tax Act shall be applicable to investments in qualified property as set forth in subdivision (a)(3)(A) of this Section.

(b-5) Businesses designated as High Impact Businesses pursuant to subdivisions (a)(3)(B), (a)(3)(B-5), (a)(3)(C), (a)(3)(D), (a)(3)(G), and (a)(3)(H) of this Section shall qualify for the credits and exemptions described in the following Acts: Section 51 of the Retailers' Occupation Tax Act, Section 9-222 and Section 9-222.1A of the Public Utilities Act, and subsection (h) of Section 201 of the Illinois Income Tax Act; however, the credits and exemptions authorized under Section 9-222 and Section 9-222.1A of the Public Utilities Act, and subsection (h) of Section 201 of the Illinois Income Tax Act shall not be authorized until the new electric generating facility, the new gasification facility, the new transmission facility, the new, expanded, or reopened coal mine, the new cultured cell material food production facility, or the existing or planned grocery store is operational, except that a new electric generating facility whose primary fuel source is natural gas is eligible only for the exemption under Section 5l of the Retailers' Occupation Tax Act.

(b-6) Businesses designated as High Impact Businesses pursuant to subdivision (a)(3)(E), or (a)(3)(E-5), (A)(3)(I), or (a)(3)(J) of this Section shall qualify for the exemptions described in Section 5l of the Retailers' Occupation Tax Act; any business so designated as a High Impact Business being, for purposes of this Section, a "Wind Energy Business".

(b-7) Beginning on January 1, 2021, businesses designated as High Impact Businesses by the Department shall qualify for the High Impact Business construction jobs credit under subsection (h-5) of Section 201 of the Illinois Income Tax Act if the business meets the criteria set forth in subsection (i) of this Section. The total aggregate amount of credits awarded under the Blue Collar Jobs Act (Article 20 of Public Act 101-9) shall not exceed $20,000,000 in any State fiscal year.

(c) High Impact Businesses located in federally designated foreign trade zones or sub-zones are also eligible for additional credits, exemptions and deductions as described in the following Acts: Section 9-221 and Section 9-222.1 of the Public Utilities Act; and subsection (g) of Section 201, and Section 203 of the Illinois Income Tax Act.

(d) Except for businesses contemplated under subdivision (a)(3)(E), (a)(3)(E-5), (a)(3)(G), or (a)(3)(H), (A)(3)(I), or (a)(3)(J) of this Section, existing Illinois businesses which apply for designation as a High Impact Business must provide the Department with the prospective plan for which 1,500 full-time retained jobs would be eliminated in the event that the business is not designated.

(e) Except for new businesses contemplated under subdivision (a)(3)(E), subdivision (a)(3)(G), or subdivision (a)(3)(H), or subdivision (a)(3)(J) of this Section, new proposed facilities which apply for designation as High Impact Business must provide the Department with proof of alternative non-Illinois sites which would receive the proposed investment and job creation in the event that the business is not designated as a High Impact Business.

(f) Except for businesses contemplated under subdivision (a)(3)(E), subdivision (a)(3)(G), or subdivision (a)(3)(H), or subdivision (a)(3)(J) of this Section, in the event that a business is designated a High Impact Business and it is later determined after reasonable notice and an opportunity for a hearing as provided under the Illinois Administrative Procedure Act, that the business would have placed in service in qualified property the investments and created or retained the requisite number of jobs without the benefits of the High Impact Business designation, the Department shall be required to immediately revoke the designation and notify the Director of the Department of Revenue who shall begin proceedings to recover all wrongfully exempted State taxes with interest. The business shall also be ineligible for all State funded Department programs for a period of 10 years.

(g) The Department shall revoke a High Impact Business designation if the participating business fails to comply with the terms and conditions of the designation.

(h) Prior to designating a business, the Department shall provide the members of the General Assembly and Commission on Government Forecasting and Accountability with a report setting forth the terms and conditions of the designation and guarantees that have been received by the Department in relation to the proposed business being designated.

(i) High Impact Business construction jobs credit. Beginning on January 1, 2021, a High Impact Business may receive a tax credit against the tax imposed under subsections (a) and (b) of Section 201 of the Illinois Income Tax Act in an amount equal to 50% of the amount of the incremental income tax attributable to High Impact Business construction jobs credit employees employed in the course of completing a High Impact Business construction jobs project. However, the High Impact Business construction jobs credit may equal 75% of the amount of the incremental income tax attributable to High Impact Business construction jobs credit employees if the High Impact Business construction jobs credit project is located in an underserved area.

The Department shall certify to the Department of Revenue: (1) the identity of taxpayers that are eligible for the High Impact Business construction jobs credit; and (2) the amount of High Impact Business construction jobs credits that are claimed pursuant to subsection (h-5) of Section 201 of the Illinois Income Tax Act in each taxable year.

As used in this subsection (i):

"High Impact Business construction jobs credit" means an amount equal to 50% (or 75% if the High Impact Business construction project is located in an underserved area) of the incremental income tax attributable to High Impact Business construction job employees. The total aggregate amount of credits awarded under the Blue Collar Jobs Act (Article 20 of Public Act 101-9) shall not exceed $20,000,000 in any State fiscal year

"High Impact Business construction job employee" means a laborer or worker who is employed by a contractor or subcontractor in the actual construction work on the site of a High Impact Business construction job project.

"High Impact Business construction jobs project" means building a structure or building or making improvements of any kind to real property, undertaken and commissioned by a business that was designated as a High Impact Business by the Department. The term "High Impact Business construction jobs project" does not include the routine operation, routine repair, or routine maintenance of existing structures, buildings, or real property.

"Incremental income tax" means the total amount withheld during the taxable year from the compensation of High Impact Business construction job employees.

"Underserved area" means a geographic area that meets one or more of the following conditions:

(1) the area has a poverty rate of at least 20% according to the latest American Community Survey;

(2) 35% or more of the families with children in the area are living below 130% of the poverty line, according to the latest American Community Survey;

(3) at least 20% of the households in the area receive assistance under the Supplemental Nutrition Assistance Program (SNAP); or

(4) the area has an average unemployment rate, as determined by the Illinois Department of Employment Security, that is more than 120% of the national unemployment average, as determined by the U.S. Department of Labor, for a period of at least 2 consecutive calendar years preceding the date of the application.

(j) (Blank).

(j-5) Annually, until construction is completed, a company seeking High Impact Business Construction Job credits shall submit a report that, at a minimum, describes the projected project scope, timeline, and anticipated budget. Once the project has commenced, the annual report shall include actual data for the prior year as well as projections for each additional year through completion of the project. The Department shall issue detailed reporting guidelines prescribing the requirements of construction-related reports.

In order to receive credit for construction expenses, the company must provide the Department with evidence that a certified third-party executed an Agreed-Upon Procedure (AUP) verifying the construction expenses or accept the standard construction wage expense estimated by the Department.

Upon review of the final project scope, timeline, budget, and AUP, the Department shall issue a tax credit certificate reflecting a percentage of the total construction job wages paid throughout the completion of the project.

(k) Upon 7 business days' notice, each taxpayer shall make available to each State agency and to federal, State, or local law enforcement agencies and prosecutors for inspection and copying at a location within this State during reasonable hours, the report under subsection (j-5).

(l) The changes made to this Section by Public Act 102-1125, other than the changes in subsection (a), apply to High Impact Businesses that submit applications on or after February 3, 2023 (the effective date of Public Act 102-1125).

(Source: P.A. 102-108, eff. 1-1-22; 102-558, eff. 8-20-21; 102-605, eff. 8-27-21; 102-662, eff. 9-15-21; 102-673, eff. 11-30-21; 102-813, eff. 5-13-22; 102-1125, eff. 2-3-23; 103-9, eff. 6-7-23; 103-561, eff. 1-1-24; 103-595, eff. 6-26-24; 103-605, eff. 7-1-24.)

Section 55. The Energy Community Reinvestment Act is amended by changing Section 10-20 as follows:

(20 ILCS 735/10-20)

(Section scheduled to be repealed on September 15, 2045)

Sec. 10-20. Energy Transition Community Grants.

(a) Subject to appropriation, the Department shall establish an Energy Transition Community Grant Program to award grants to promote economic development in eligible communities.

(b) Funds shall be made available from the Energy Transition Assistance Fund to the Department to provide these grants.

(c) Communities eligible to receive these grants must meet one or more of the following:

(1) the area contains a fossil fuel or nuclear power plant that was retired from service or has significantly reduced service within 6 years before the application for designation or will be retired or have service significantly reduced within 6 years following the application for designation;

(2) the area contains a coal mine that was closed or had operations significantly reduced within 6 years before the application for designation or is anticipated to be closed or have operations significantly reduced within 6 years following the application for designation; or

(3) the area contains a nuclear power plant that was decommissioned, but continued storing nuclear waste before the effective date of this Act.

(d) Local units of governments in eligible areas may join with any other local unit of government, economic development organization, local educational institutions, community-based groups, or with any number or combination thereof to apply for the Energy Transition Community Grant.

(e) To receive grant funds, an eligible community must submit an application to the Department, using a form developed by the Department.

(f) For grants awarded to counties or other entities that are not the city that hosts or has hosted the investor-owned electric generating plant, a resolution of support for the project from the city or cities that hosts or has hosted the investor-owned electric generating plant is required to be submitted with the application.

(g) Grants must be used to plan for or address the economic and social impact on the community or region of plant retirement or transition.

(h) Project applications shall include community input and consultation with a diverse set of stakeholders, including, but not limited to: Regional Planning Councils, where applicable; economic development organizations; low-income or environmental justice communities; educational institutions; elected and appointed officials; organizations representing workers; and other relevant organizations.

(i) Grant costs are authorized to procure third-party vendors for grant writing and implementation costs, including for guidance and opportunities to apply for additional federal, State, local, and private funding resources. If the application is approved for pre-award, one-time reimbursable costs to apply for the Energy Transition Community Grant are authorized up to 3% of the award.

(j) Units of local government that are taxing authorities for a nuclear plant that was decommissioned before January 1, 2021 shall receive grants in proportional shares of $15 per kilogram of spent nuclear fuel stored at such a facility, less any payments made to such communities from the federal government based on the amount of waste stored at a decommissioned nuclear plant and any property tax payments. 75% of grant funds received by taxing authorities must be used for property tax abatement purposes.

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

Section 60. The Illinois Power Agency Act is amended by changing Sections 1-56 and 1-75 as follows:

(20 ILCS 3855/1-56)

Sec. 1-56. Illinois Power Agency Renewable Energy Resources Fund; Illinois Solar for All Program.

(a) The Illinois Power Agency Renewable Energy Resources Fund is created as a special fund in the State treasury.

(b) The Illinois Power Agency Renewable Energy Resources Fund shall be administered by the Agency as described in this subsection (b), provided that the changes to this subsection (b) made by Public Act 99-906 shall not interfere with existing contracts under this Section.

(1) The Illinois Power Agency Renewable Energy Resources Fund shall be used to purchase renewable energy credits according to any approved procurement plan developed by the Agency prior to June 1, 2017.

(2) The Illinois Power Agency Renewable Energy Resources Fund shall also be used to create the Illinois Solar for All Program, which provides incentives for low-income distributed generation and community solar projects, and other associated approved expenditures. The objectives of the Illinois Solar for All Program are to bring photovoltaics to low-income communities in this State in a manner that maximizes the development of new photovoltaic generating facilities, to create a long-term, low-income solar marketplace throughout this State, to integrate, through interaction with stakeholders, with existing energy efficiency initiatives, and to minimize administrative costs. The Illinois Solar for All Program shall be implemented in a manner that seeks to minimize administrative costs, and maximize efficiencies and synergies available through coordination with similar initiatives, including the Adjustable Block program described in subparagraphs (K) through (M) of paragraph (1) of subsection (c) of Section 1-75, energy efficiency programs, job training programs, and community action agencies. The Agency shall strive to ensure that renewable energy credits procured through the Illinois Solar for All Program and each of its subprograms are purchased from projects across the breadth of low-income and environmental justice communities in Illinois, including both urban and rural communities, are not concentrated in a few communities, and do not exclude particular low-income or environmental justice communities. The Agency shall include a description of its proposed approach to the design, administration, implementation and evaluation of the Illinois Solar for All Program, as part of the long-term renewable resources procurement plan authorized by subsection (c) of Section 1-75 of this Act, and the program shall be designed to grow the low-income solar market. The Agency or utility, as applicable, shall purchase renewable energy credits from the (i) photovoltaic distributed renewable energy generation projects and (ii) community solar projects that are procured under procurement processes authorized by the long-term renewable resources procurement plans approved by the Commission.

The Illinois Solar for All Program shall include the program offerings described in subparagraphs (A) through (E) of this paragraph (2), which the Agency shall implement through contracts with third-party providers and, subject to appropriation, pay the approximate amounts identified using monies available in the Illinois Power Agency Renewable Energy Resources Fund. Each contract that provides for the installation of solar facilities shall provide that the solar facilities will produce energy and economic benefits, at a level determined by the Agency to be reasonable, for the participating low-income customers. The monies available in the Illinois Power Agency Renewable Energy Resources Fund and not otherwise committed to contracts executed under subsection (i) of this Section, as well as, in the case of the programs described under subparagraphs (A) through (E) of this paragraph (2), funding authorized pursuant to subparagraph (O) of paragraph (1) of subsection (c) of Section 1-75 of this Act, shall initially be allocated among the programs described in this paragraph (2), as follows: 35% of these funds shall be allocated to programs described in subparagraphs (A) and (E) of this paragraph (2), 40% of these funds shall be allocated to programs described in subparagraph (B) of this paragraph (2), and 25% of these funds shall be allocated to programs described in subparagraph (C) of this paragraph (2). The allocation of funds among subparagraphs (A), (B), (C), and (E) of this paragraph (2) may be changed if the Agency, after receiving input through a stakeholder process, determines incentives in subparagraphs (A), (B), (C), or (E) of this paragraph (2) have not been adequately subscribed to fully utilize available Illinois Solar for All Program funds.

Contracts that will be paid with funds in the Illinois Power Agency Renewable Energy Resources Fund shall be executed by the Agency. Contracts that will be paid with funds collected by an electric utility shall be executed by the electric utility.

Contracts under the Illinois Solar for All Program shall include an approach, as set forth in the long-term renewable resources procurement plans, to ensure the wholesale market value of the energy is credited to participating low-income customers or organizations and to ensure tangible economic benefits flow directly to program participants, except in the case of low-income multi-family housing where the low-income customer does not directly pay for energy. Priority shall be given to projects that demonstrate meaningful involvement of low-income community members in designing the initial proposals. Acceptable proposals to implement projects must demonstrate the applicant's ability to conduct initial community outreach, education, and recruitment of low-income participants in the community. Projects must include job training opportunities if available, with the specific level of trainee usage to be determined through the Agency's long-term renewable resources procurement plan, and the Illinois Solar for All Program Administrator shall coordinate with the job training programs described in paragraph (1) of subsection (a) of Section 16-108.12 of the Public Utilities Act and in the Energy Transition Act.

The Agency shall make every effort to ensure that small and emerging businesses, particularly those located in low-income and environmental justice communities, are able to participate in the Illinois Solar for All Program. These efforts may include, but shall not be limited to, proactive support from the program administrator, different or preferred access to subprograms and administrator-identified customers or grassroots education provider-identified customers, and different incentive levels. The Agency shall report on progress and barriers to participation of small and emerging businesses in the Illinois Solar for All Program at least once a year. The report shall be made available on the Agency's website and, in years when the Agency is updating its long-term renewable resources procurement plan, included in that Plan.

(A) Low-income single-family and small multifamily solar incentive. This program will provide incentives to low-income customers, either directly or through solar providers, to increase the participation of low-income households in photovoltaic on-site distributed generation at residential buildings containing one to 4 units. Companies participating in this program that install solar panels shall commit to hiring job trainees for a portion of their low-income installations, and an administrator shall facilitate partnering the companies that install solar panels with entities that provide solar panel installation job training. It is a goal of this program that a minimum of 25% of the incentives for this program be allocated to projects located within environmental justice communities. Contracts entered into under this paragraph may be entered into with an entity that will develop and administer the program and shall also include contracts for renewable energy credits from the photovoltaic distributed generation that is the subject of the program, as set forth in the long-term renewable resources procurement plan. Additionally:

(i) The Agency shall reserve a portion of this program for projects that promote energy sovereignty through ownership of projects by low-income households, not-for-profit organizations providing services to low-income households, affordable housing owners, community cooperatives, or community-based limited liability companies providing services to low-income households. Projects that feature energy ownership should ensure that local people have control of the project and reap benefits from the project over and above energy bill savings. The Agency may consider the inclusion of projects that promote ownership over time or that involve partial project ownership by communities, as promoting energy sovereignty. Incentives for projects that promote energy sovereignty may be higher than incentives for equivalent projects that do not promote energy sovereignty under this same program.

(ii) Through its long-term renewable resources procurement plan, the Agency shall consider additional program and contract requirements to ensure faithful compliance by applicants benefiting from preferences for projects designated to promote energy sovereignty. The Agency shall make every effort to enable solar providers already participating in the Adjustable Block Program under subparagraph (K) of paragraph (1) of subsection (c) of Section 1-75 of this Act, and particularly solar providers developing projects under item (i) of subparagraph (K) of paragraph (1) of subsection (c) of Section 1-75 of this Act to easily participate in the Low-Income Distributed Generation Incentive program described under this subparagraph (A), and vice versa. This effort may include, but shall not be limited to, utilizing similar or the same application systems and processes, similar or the same forms and formats of communication, and providing active outreach to companies participating in one program but not the other. The Agency shall report on efforts made to encourage this cross-participation in its long-term renewable resources procurement plan.

(B) Low-Income Community Solar Project Initiative. Incentives shall be offered to low-income customers, either directly or through developers, to increase the participation of low-income subscribers of community solar projects. The developer of each project shall identify its partnership with community stakeholders regarding the location, development, and participation in the project, provided that nothing shall preclude a project from including an anchor tenant that does not qualify as low-income. Companies participating in this program that develop or install solar projects shall commit to hiring job trainees for a portion of their low-income installations, and an administrator shall facilitate partnering the companies that install solar projects with entities that provide solar installation and related job training. It is a goal of this program that a minimum of 25% of the incentives for this program be allocated to community photovoltaic projects in environmental justice communities. The Agency shall reserve a portion of this program for projects that promote energy sovereignty through ownership of projects by low-income households, not-for-profit organizations providing services to low-income households, affordable housing owners, or community-based limited liability companies providing services to low-income households. Projects that feature energy ownership should ensure that local people have control of the project and reap benefits from the project over and above energy bill savings. The Agency may consider the inclusion of projects that promote ownership over time or that involve partial project ownership by communities, as promoting energy sovereignty. Incentives for projects that promote energy sovereignty may be higher than incentives for equivalent projects that do not promote energy sovereignty under this same program. Contracts entered into under this paragraph may be entered into with developers and shall also include contracts for renewable energy credits related to the program.

(C) Incentives for non-profits and public facilities. Under this program funds shall be used to support on-site photovoltaic distributed renewable energy generation devices to serve the load associated with not-for-profit customers and to support photovoltaic distributed renewable energy generation that uses photovoltaic technology to serve the load associated with public sector customers taking service at public buildings. Companies participating in this program that develop or install solar projects shall commit to hiring job trainees for a portion of their low-income installations, and an administrator shall facilitate partnering the companies that install solar projects with entities that provide solar installation and related job training. Through its long-term renewable resources procurement plan, the Agency shall consider additional program and contract requirements to ensure faithful compliance by applicants benefiting from preferences for projects designated to promote energy sovereignty. It is a goal of this program that at least 25% of the incentives for this program be allocated to projects located in environmental justice communities. Contracts entered into under this paragraph may be entered into with an entity that will develop and administer the program or with developers and shall also include contracts for renewable energy credits related to the program.

(D) (Blank).

(E) Low-income large multifamily solar incentive. This program shall provide incentives to low-income customers, either directly or through solar providers, to increase the participation of low-income households in photovoltaic on-site distributed generation at residential buildings with 5 or more units. Companies participating in this program that develop or install solar projects shall commit to hiring job trainees for a portion of their low-income installations, and an administrator shall facilitate partnering the companies that install solar projects with entities that provide solar installation and related job training. It is a goal of this program that a minimum of 25% of the incentives for this program be allocated to projects located within environmental justice communities. The Agency shall reserve a portion of this program for projects that promote energy sovereignty through ownership of projects by low-income households, not-for-profit organizations providing services to low-income households, affordable housing owners, or community-based limited liability companies providing services to low-income households. Projects that feature energy ownership should ensure that local people have control of the project and reap benefits from the project over and above energy bill savings. The Agency may consider the inclusion of projects that promote ownership over time or that involve partial project ownership by communities, as promoting energy sovereignty. Incentives for projects that promote energy sovereignty may be higher than incentives for equivalent projects that do not promote energy sovereignty under this same program.

The requirement that a qualified person, as defined in paragraph (1) of subsection (i) of this Section, install photovoltaic devices does not apply to the Illinois Solar for All Program described in this subsection (b).

In addition to the programs outlined in paragraphs (A) through (E), the Agency and other parties may propose additional programs through the Long-Term Renewable Resources Procurement Plan developed and approved under paragraph (5) of subsection (b) of Section 16-111.5 of the Public Utilities Act. Additional programs may target market segments not specified above and may also include incentives targeted to increase the uptake of nonphotovoltaic technologies by low-income customers, including energy storage paired with photovoltaics, if the Commission determines that the Illinois Solar for All Program would provide greater benefits to the public health and well-being of low-income residents through also supporting that additional program versus supporting programs already authorized.

(3) Costs associated with the Illinois Solar for All Program and its components described in paragraph (2) of this subsection (b), including, but not limited to, costs associated with procuring experts, consultants, and the program administrator referenced in this subsection (b) and related incremental costs, costs related to income verification and facilitating customer participation in the program, and costs related to the evaluation of the Illinois Solar for All Program, may be paid for using monies in the Illinois Power Agency Renewable Energy Resources Fund, and funds allocated pursuant to subparagraph (O) of paragraph (1) of subsection (c) of Section 1-75, but the Agency or program administrator shall strive to minimize costs in the implementation of the program. The Agency or contracting electric utility shall purchase renewable energy credits from generation that is the subject of a contract under subparagraphs (A) through (E) of paragraph (2) of this subsection (b), and may pay for such renewable energy credits through an upfront payment per installed kilowatt of nameplate capacity paid once the device is interconnected at the distribution system level of the interconnecting utility and verified as energized. Payments for renewable energy credits shall be in exchange for all renewable energy credits generated by the system during the first 15 years of operation and shall be structured to overcome barriers to participation in the solar market by the low-income community. The incentives provided for in this Section may be implemented through the pricing of renewable energy credits where the prices paid for the credits are higher than the prices from programs offered under subsection (c) of Section 1-75 of this Act to account for the additional capital necessary to successfully access targeted market segments. The Agency or contracting electric utility shall retire any renewable energy credits purchased under this program and the credits shall count toward the obligation under subsection (c) of Section 1-75 of this Act for the electric utility to which the project is interconnected, if applicable.

The Agency shall direct that up to 5% of the funds available under the Illinois Solar for All Program to community-based groups and other qualifying organizations to assist in community-driven education efforts related to the Illinois Solar for All Program, including general energy education, job training program outreach efforts, and other activities deemed to be qualified by the Agency. Grassroots education funding shall not be used to support the marketing by solar project development firms and organizations, unless such education provides equal opportunities for all applicable firms and organizations.

(4) The Agency shall, consistent with the requirements of this subsection (b), propose the Illinois Solar for All Program terms, conditions, and requirements, including the prices to be paid for renewable energy credits, and which prices may be determined through a formula, through the development, review, and approval of the Agency's long-term renewable resources procurement plan described in subsection (c) of Section 1-75 of this Act and Section 16-111.5 of the Public Utilities Act. In the course of the Commission proceeding initiated to review and approve the plan, including the Illinois Solar for All Program proposed by the Agency, a party may propose an additional low-income solar or solar incentive program, or modifications to the programs proposed by the Agency, and the Commission may approve an additional program, or modifications to the Agency's proposed program, if the additional or modified program more effectively maximizes the benefits to low-income customers after taking into account all relevant factors, including, but not limited to, the extent to which a competitive market for low-income solar has developed. Following the Commission's approval of the Illinois Solar for All Program, the Agency or a party may propose adjustments to the program terms, conditions, and requirements, including the price offered to new systems, to ensure the long-term viability and success of the program. The Commission shall review and approve any modifications to the program through the plan revision process described in Section 16-111.5 of the Public Utilities Act.

(5) The Agency shall issue a request for qualifications for a third-party program administrator or administrators to administer all or a portion of the Illinois Solar for All Program. The third-party program administrator shall be chosen through a competitive bid process based on selection criteria and requirements developed by the Agency, including, but not limited to, experience in administering low-income energy programs and overseeing statewide clean energy or energy efficiency services. If the Agency retains a program administrator or administrators to implement all or a portion of the Illinois Solar for All Program, each administrator shall periodically submit reports to the Agency and Commission for each program that it administers, at appropriate intervals to be identified by the Agency in its long-term renewable resources procurement plan, provided that the reporting interval is at least quarterly. The third-party program administrator may be, but need not be, the same administrator as for the Adjustable Block program described in subparagraphs (K) through (M) of paragraph (1) of subsection (c) of Section 1-75. The Agency, through its long-term renewable resources procurement plan approval process, shall also determine if individual subprograms of the Illinois Solar for All Program are better served by a different or separate Program Administrator.

The third-party administrator's responsibilities shall also include facilitating placement for graduates of Illinois-based renewable energy-specific job training programs, including the Clean Jobs Workforce Network Program and the Illinois Climate Works Preapprenticeship Program administered by the Department of Commerce and Economic Opportunity and programs administered under Section 16-108.12 of the Public Utilities Act. To increase the uptake of trainees by participating firms, the administrator shall also develop a web-based clearinghouse for information available to both job training program graduates and firms participating, directly or indirectly, in Illinois solar incentive programs. The program administrator shall also coordinate its activities with entities implementing electric and natural gas income-qualified energy efficiency programs, including customer referrals to and from such programs, and connect prospective low-income solar customers with any existing deferred maintenance programs where applicable.

(6) The long-term renewable resources procurement plan shall also provide for an independent evaluation of the Illinois Solar for All Program. At least every 2 years, the Agency shall select an independent evaluator to review and report on the Illinois Solar for All Program and the performance of the third-party program administrator of the Illinois Solar for All Program. The evaluation shall be based on objective criteria developed through a public stakeholder process. The process shall include feedback and participation from Illinois Solar for All Program stakeholders, including participants and organizations in environmental justice and historically underserved communities. The report shall include a summary of the evaluation of the Illinois Solar for All Program based on the stakeholder developed objective criteria. The report shall include the number of projects installed; the total installed capacity in kilowatts; the average cost per kilowatt of installed capacity to the extent reasonably obtainable by the Agency; the number of jobs or job opportunities created; economic, social, and environmental benefits created; and the total administrative costs expended by the Agency and program administrator to implement and evaluate the program. The report shall be delivered to the Commission and posted on the Agency's website, and shall be used, as needed, to revise the Illinois Solar for All Program. The Commission shall also consider the results of the evaluation as part of its review of the long-term renewable resources procurement plan under subsection (c) of Section 1-75 of this Act.

(7) If additional funding for the programs described in this subsection (b) is available under subsection (k) of Section 16-108 of the Public Utilities Act, then the Agency shall submit a procurement plan to the Commission no later than September 1, 2018, that proposes how the Agency will procure programs on behalf of the applicable utility. After notice and hearing, the Commission shall approve, or approve with modification, the plan no later than November 1, 2018.

(8) As part of the development and update of the long-term renewable resources procurement plan authorized by subsection (c) of Section 1-75 of this Act, the Agency shall plan for: (A) actions to refer customers from the Illinois Solar for All Program to electric and natural gas income-qualified energy efficiency programs, and vice versa, with the goal of increasing participation in both of these programs; (B) effective procedures for data sharing, as needed, to effectuate referrals between the Illinois Solar for All Program and both electric and natural gas income-qualified energy efficiency programs, including sharing customer information directly with the utilities, as needed and appropriate; and (C) efforts to identify any existing deferred maintenance programs for which prospective Solar for All Program customers may be eligible and connect prospective customers for whom deferred maintenance is or may be a barrier to solar installation to those programs.

As used in this subsection (b), "low-income households" means persons and families whose income does not exceed 80% of area median income, adjusted for family size and revised every year 5 years.

For the purposes of this subsection (b), the Agency shall define "environmental justice community" based on the methodologies and findings established by the Agency and the Administrator for the Illinois Solar for All Program in its initial long-term renewable resources procurement plan and as updated by the Agency and the Administrator for the Illinois Solar for All Program as part of the long-term renewable resources procurement plan update.

(b-5) After the receipt of all payments required by Section 16-115D of the Public Utilities Act, no additional funds shall be deposited into the Illinois Power Agency Renewable Energy Resources Fund unless directed by order of the Commission.

(b-10) After the receipt of all payments required by Section 16-115D of the Public Utilities Act and payment in full of all contracts executed by the Agency under subsections (b) and (i) of this Section, if the balance of the Illinois Power Agency Renewable Energy Resources Fund is under $5,000, then the Fund shall be inoperative and any remaining funds and any funds submitted to the Fund after that date, shall be transferred to the Supplemental Low-Income Energy Assistance Fund for use in the Low-Income Home Energy Assistance Program, as authorized by the Energy Assistance Act.

(b-15) The prevailing wage requirements set forth in the Prevailing Wage Act apply to each project that is undertaken pursuant to one or more of the programs of incentives and initiatives described in subsection (b) of this Section and for which a project application is submitted to the program after the effective date of this amendatory Act of the 103rd General Assembly, except (i) projects that serve single-family or multi-family residential buildings and (ii) projects with an aggregate capacity of less than 100 kilowatts that serve houses of worship. The Agency shall require verification that all construction performed on a project by the renewable energy credit delivery contract holder, its contractors, or its subcontractors relating to the construction of the facility is performed by workers receiving an amount for that work that is greater than or equal to the general prevailing rate of wages as that term is defined in the Prevailing Wage Act, and the Agency may adjust renewable energy credit prices to account for increased labor costs.

In this subsection (b-15), "house of worship" has the meaning given in subparagraph (Q) of paragraph (1) of subsection (c) of Section 1-75.

(c) (Blank).

(d) (Blank).

(e) All renewable energy credits procured using monies from the Illinois Power Agency Renewable Energy Resources Fund shall be permanently retired.

(f) The selection of one or more third-party program managers or administrators, the selection of the independent evaluator, and the procurement processes described in this Section are exempt from the requirements of the Illinois Procurement Code, under Section 20-10 of that Code.

(g) All disbursements from the Illinois Power Agency Renewable Energy Resources Fund shall be made only upon warrants of the Comptroller drawn upon the Treasurer as custodian of the Fund upon vouchers signed by the Director 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.

(h) The Illinois Power Agency Renewable Energy Resources Fund shall not be subject to sweeps, administrative charges, or chargebacks, including, but not limited to, those authorized under Section 8h of the State Finance Act, that would in any way result in the transfer of any funds from this Fund to any other fund of this State or in having any such funds utilized for any purpose other than the express purposes set forth in this Section.

(h-5) The Agency may assess fees to each bidder to recover the costs incurred in connection with a procurement process held under this Section. Fees collected from bidders shall be deposited into the Renewable Energy Resources Fund.

(i) Supplemental procurement process.

(1) Within 90 days after June 30, 2014 (the effective date of Public Act 98-672), the Agency shall develop a one-time supplemental procurement plan limited to the procurement of renewable energy credits, if available, from new or existing photovoltaics, including, but not limited to, distributed photovoltaic generation. Nothing in this subsection (i) requires procurement of wind generation through the supplemental procurement.

Renewable energy credits procured from new photovoltaics, including, but not limited to, distributed photovoltaic generation, under this subsection (i) must be procured from devices installed by a qualified person. In its supplemental procurement plan, the Agency shall establish contractually enforceable mechanisms for ensuring that the installation of new photovoltaics is performed by a qualified person.

For the purposes of this paragraph (1), "qualified person" means a person who performs installations of photovoltaics, including, but not limited to, distributed photovoltaic generation, and who: (A) has completed an apprenticeship as a journeyman electrician from a United States Department of Labor registered electrical apprenticeship and training program and received a certification of satisfactory completion; or (B) does not currently meet the criteria under clause (A) of this paragraph (1), but is enrolled in a United States Department of Labor registered electrical apprenticeship program, provided that the person is directly supervised by a person who meets the criteria under clause (A) of this paragraph (1); or (C) has obtained one of the following credentials in addition to attesting to satisfactory completion of at least 5 years or 8,000 hours of documented hands-on electrical experience: (i) a North American Board of Certified Energy Practitioners (NABCEP) Installer Certificate for Solar PV; (ii) an Underwriters Laboratories (UL) PV Systems Installer Certificate; (iii) an Electronics Technicians Association, International (ETAI) Level 3 PV Installer Certificate; or (iv) an Associate in Applied Science degree from an Illinois Community College Board approved community college program in renewable energy or a distributed generation technology.

For the purposes of this paragraph (1), "directly supervised" means that there is a qualified person who meets the qualifications under clause (A) of this paragraph (1) and who is available for supervision and consultation regarding the work performed by persons under clause (B) of this paragraph (1), including a final inspection of the installation work that has been directly supervised to ensure safety and conformity with applicable codes.

For the purposes of this paragraph (1), "install" means the major activities and actions required to connect, in accordance with applicable building and electrical codes, the conductors, connectors, and all associated fittings, devices, power outlets, or apparatuses mounted at the premises that are directly involved in delivering energy to the premises' electrical wiring from the photovoltaics, including, but not limited to, to distributed photovoltaic generation.

The renewable energy credits procured pursuant to the supplemental procurement plan shall be procured using up to $30,000,000 from the Illinois Power Agency Renewable Energy Resources Fund. The Agency shall not plan to use funds from the Illinois Power Agency Renewable Energy Resources Fund in excess of the monies on deposit in such fund or projected to be deposited into such fund. The supplemental procurement plan shall ensure adequate, reliable, affordable, efficient, and environmentally sustainable renewable energy resources (including credits) at the lowest total cost over time, taking into account any benefits of price stability.

To the extent available, 50% of the renewable energy credits procured from distributed renewable energy generation shall come from devices of less than 25 kilowatts in nameplate capacity. Procurement of renewable energy credits from distributed renewable energy generation devices shall be done through multi-year contracts of no less than 5 years. The Agency shall create credit requirements for counterparties. In order to minimize the administrative burden on contracting entities, the Agency shall solicit the use of third parties to aggregate distributed renewable energy. These third parties shall enter into and administer contracts with individual distributed renewable energy generation device owners. An individual distributed renewable energy generation device owner shall have the ability to measure the output of his or her distributed renewable energy generation device.

In developing the supplemental procurement plan, the Agency shall hold at least one workshop open to the public within 90 days after June 30, 2014 (the effective date of Public Act 98-672) and shall consider any comments made by stakeholders or the public. Upon development of the supplemental procurement plan within this 90-day period, copies of the supplemental procurement plan shall be posted and made publicly available on the Agency's and Commission's websites. All interested parties shall have 14 days following the date of posting to provide comment to the Agency on the supplemental procurement plan. All comments submitted to the Agency shall be specific, supported by data or other detailed analyses, and, if objecting to all or a portion of the supplemental procurement plan, accompanied by specific alternative wording or proposals. All comments shall be posted on the Agency's and Commission's websites. Within 14 days following the end of the 14-day review period, the Agency shall revise the supplemental procurement plan as necessary based on the comments received and file its revised supplemental procurement plan with the Commission for approval.

(2) Within 5 days after the filing of the supplemental procurement plan at the Commission, any person objecting to the supplemental procurement plan shall file an objection with the Commission. Within 10 days after the filing, the Commission shall determine whether a hearing is necessary. The Commission shall enter its order confirming or modifying the supplemental procurement plan within 90 days after the filing of the supplemental procurement plan by the Agency.

(3) The Commission shall approve the supplemental procurement plan of renewable energy credits to be procured from new or existing photovoltaics, including, but not limited to, distributed photovoltaic generation, if the Commission determines that it will ensure adequate, reliable, affordable, efficient, and environmentally sustainable electric service in the form of renewable energy credits at the lowest total cost over time, taking into account any benefits of price stability.

(4) The supplemental procurement process under this subsection (i) shall include each of the following components:

(A) Procurement administrator. The Agency may retain a procurement administrator in the manner set forth in item (2) of subsection (a) of Section 1-75 of this Act to conduct the supplemental procurement or may elect to use the same procurement administrator administering the Agency's annual procurement under Section 1-75.

(B) Procurement monitor. The procurement monitor retained by the Commission pursuant to Section 16-111.5 of the Public Utilities Act shall:

(i) monitor interactions among the procurement administrator and bidders and suppliers;

(ii) monitor and report to the Commission on the progress of the supplemental procurement process;

(iii) provide an independent confidential report to the Commission regarding the results of the procurement events;

(iv) assess compliance with the procurement plan approved by the Commission for the supplemental procurement process;

(v) preserve the confidentiality of supplier and bidding information in a manner consistent with all applicable laws, rules, regulations, and tariffs;

(vi) provide expert advice to the Commission and consult with the procurement administrator regarding issues related to procurement process design, rules, protocols, and policy-related matters;

(vii) consult with the procurement administrator regarding the development and use of benchmark criteria, standard form contracts, credit policies, and bid documents; and

(viii) perform, with respect to the supplemental procurement process, any other procurement monitor duties specifically delineated within subsection (i) of this Section.

(C) Solicitation, prequalification, and registration of bidders. The procurement administrator shall disseminate information to potential bidders to promote a procurement event, notify potential bidders that the procurement administrator may enter into a post-bid price negotiation with bidders that meet the applicable benchmarks, provide supply requirements, and otherwise explain the competitive procurement process. In addition to such other publication as the procurement administrator determines is appropriate, this information shall be posted on the Agency's and the Commission's websites. The procurement administrator shall also administer the prequalification process, including evaluation of credit worthiness, compliance with procurement rules, and agreement to the standard form contract developed pursuant to item (D) of this paragraph (4). The procurement administrator shall then identify and register bidders to participate in the procurement event.

(D) Standard contract forms and credit terms and instruments. The procurement administrator, in consultation with the Agency, the Commission, and other interested parties and subject to Commission oversight, shall develop and provide standard contract forms for the supplier contracts that meet generally accepted industry practices as well as include any applicable State of Illinois terms and conditions that are required for contracts entered into by an agency of the State of Illinois. Standard credit terms and instruments that meet generally accepted industry practices shall be similarly developed. Contracts for new photovoltaics shall include a provision attesting that the supplier will use a qualified person for the installation of the device pursuant to paragraph (1) of subsection (i) of this Section. The procurement administrator shall make available to the Commission all written comments it receives on the contract forms, credit terms, or instruments. If the procurement administrator cannot reach agreement with the parties as to the contract terms and conditions, the procurement administrator must notify the Commission of any disputed terms and the Commission shall resolve the dispute. The terms of the contracts shall not be subject to negotiation by winning bidders, and the bidders must agree to the terms of the contract in advance so that winning bids are selected solely on the basis of price.

(E) Requests for proposals; competitive procurement process. The procurement administrator shall design and issue requests for proposals to supply renewable energy credits in accordance with the supplemental procurement plan, as approved by the Commission. The requests for proposals shall set forth a procedure for sealed, binding commitment bidding with pay-as-bid settlement, and provision for selection of bids on the basis of price, provided, however, that no bid shall be accepted if it exceeds the benchmark developed pursuant to item (F) of this paragraph (4).

(F) Benchmarks. Benchmarks for each product to be procured shall be developed by the procurement administrator in consultation with Commission staff, the Agency, and the procurement monitor for use in this supplemental procurement.

(G) A plan for implementing contingencies in the event of supplier default, Commission rejection of results, or any other cause.

(5) Within 2 business days after opening the sealed bids, the procurement administrator shall submit a confidential report to the Commission. The report shall contain the results of the bidding for each of the products along with the procurement administrator's recommendation for the acceptance and rejection of bids based on the price benchmark criteria and other factors observed in the process. The procurement monitor also shall submit a confidential report to the Commission within 2 business days after opening the sealed bids. The report shall contain the procurement monitor's assessment of bidder behavior in the process as well as an assessment of the procurement administrator's compliance with the procurement process and rules. The Commission shall review the confidential reports submitted by the procurement administrator and procurement monitor and shall accept or reject the recommendations of the procurement administrator within 2 business days after receipt of the reports.

(6) Within 3 business days after the Commission decision approving the results of a procurement event, the Agency shall enter into binding contractual arrangements with the winning suppliers using the standard form contracts.

(7) The names of the successful bidders and the average of the winning bid prices for each contract type and for each contract term shall be made available to the public within 2 days after the supplemental procurement event. The Commission, the procurement monitor, the procurement administrator, the Agency, and all participants in the procurement process shall maintain the confidentiality of all other supplier and bidding information in a manner consistent with all applicable laws, rules, regulations, and tariffs. Confidential information, including the confidential reports submitted by the procurement administrator and procurement monitor pursuant to this Section, shall not be made publicly available and shall not be discoverable by any party in any proceeding, absent a compelling demonstration of need, nor shall those reports be admissible in any proceeding other than one for law enforcement purposes.

(8) The supplemental procurement provided in this subsection (i) shall not be subject to the requirements and limitations of subsections (c) and (d) of this Section.

(9) Expenses incurred in connection with the procurement process held pursuant to this Section, including, but not limited to, the cost of developing the supplemental procurement plan, the procurement administrator, procurement monitor, and the cost of the retirement of renewable energy credits purchased pursuant to the supplemental procurement shall be paid for from the Illinois Power Agency Renewable Energy Resources Fund. The Agency shall enter into an interagency agreement with the Commission to reimburse the Commission for its costs associated with the procurement monitor for the supplemental procurement process.

(Source: P.A. 102-662, eff. 9-15-21; 103-188, eff. 6-30-23; 103-605, eff. 7-1-24.)

(20 ILCS 3855/1-75)

Sec. 1-75. Planning and Procurement Bureau. The Planning and Procurement Bureau has the following duties and responsibilities:

(a) The Planning and Procurement Bureau shall each year, beginning in 2008, develop procurement plans and conduct competitive procurement processes in accordance with the requirements of Section 16-111.5 of the Public Utilities Act for the eligible retail customers of electric utilities that on December 31, 2005 provided electric service to at least 100,000 customers in Illinois. Beginning with the delivery year commencing on June 1, 2017, the Planning and Procurement Bureau shall develop plans and processes for the procurement of zero emission credits from zero emission facilities in accordance with the requirements of subsection (d-5) of this Section. Beginning on the effective date of this amendatory Act of the 102nd General Assembly, the Planning and Procurement Bureau shall develop plans and processes for the procurement of carbon mitigation credits from carbon-free energy resources in accordance with the requirements of subsection (d-10) of this Section. The Planning and Procurement Bureau shall also develop procurement plans and conduct competitive procurement processes in accordance with the requirements of Section 16-111.5 of the Public Utilities Act for the eligible retail customers of small multi-jurisdictional electric utilities that (i) on December 31, 2005 served less than 100,000 customers in Illinois and (ii) request a procurement plan for their Illinois jurisdictional load. This Section shall not apply to a small multi-jurisdictional utility until such time as a small multi-jurisdictional utility requests the Agency to prepare a procurement plan for their Illinois jurisdictional load. For the purposes of this Section, the term "eligible retail customers" has the same definition as found in Section 16-111.5(a) of the Public Utilities Act.

Beginning with the plan or plans to be implemented in the 2017 delivery year, the Agency shall no longer include the procurement of renewable energy resources in the annual procurement plans required by this subsection (a), except as provided in subsection (q) of Section 16-111.5 of the Public Utilities Act, and shall instead develop a long-term renewable resources procurement plan in accordance with subsection (c) of this Section and Section 16-111.5 of the Public Utilities Act.

In accordance with subsection (c-5) of this Section, the Planning and Procurement Bureau shall oversee the procurement by electric utilities that served more than 300,000 retail customers in this State as of January 1, 2019 of renewable energy credits from new utility-scale solar projects to be installed, along with energy storage facilities, at or adjacent to the sites of electric generating facilities that, as of January 1, 2016, burned coal as their primary fuel source.

(1) The Agency shall each year, beginning in 2008, as needed, issue a request for qualifications for experts or expert consulting firms to develop the procurement plans in accordance with Section 16-111.5 of the Public Utilities Act. In order to qualify an expert or expert consulting firm must have:

(A) direct previous experience assembling large-scale power supply plans or portfolios for end-use customers;

(B) an advanced degree in economics, mathematics, engineering, risk management, or a related area of study;

(C) 10 years of experience in the electricity sector, including managing supply risk;

(D) expertise in wholesale electricity market rules, including those established by the Federal Energy Regulatory Commission and regional transmission organizations;

(E) expertise in credit protocols and familiarity with contract protocols;

(F) adequate resources to perform and fulfill the required functions and responsibilities; and

(G) the absence of a conflict of interest and inappropriate bias for or against potential bidders or the affected electric utilities.

(2) The Agency shall each year, as needed, issue a request for qualifications for a procurement administrator to conduct the competitive procurement processes in accordance with Section 16-111.5 of the Public Utilities Act. In order to qualify an expert or expert consulting firm must have:

(A) direct previous experience administering a large-scale competitive procurement process;

(B) an advanced degree in economics, mathematics, engineering, or a related area of study;

(C) 10 years of experience in the electricity sector, including risk management experience;

(D) expertise in wholesale electricity market rules, including those established by the Federal Energy Regulatory Commission and regional transmission organizations;

(E) expertise in credit and contract protocols;

(F) adequate resources to perform and fulfill the required functions and responsibilities; and

(G) the absence of a conflict of interest and inappropriate bias for or against potential bidders or the affected electric utilities.

(3) The Agency shall provide affected utilities and other interested parties with the lists of qualified experts or expert consulting firms identified through the request for qualifications processes that are under consideration to develop the procurement plans and to serve as the procurement administrator. The Agency shall also provide each qualified expert's or expert consulting firm's response to the request for qualifications. All information provided under this subparagraph shall also be provided to the Commission. The Agency may provide by rule for fees associated with supplying the information to utilities and other interested parties. These parties shall, within 5 business days, notify the Agency in writing if they object to any experts or expert consulting firms on the lists. Objections shall be based on:

(A) failure to satisfy qualification criteria;

(B) identification of a conflict of interest; or

(C) evidence of inappropriate bias for or against potential bidders or the affected utilities.

The Agency shall remove experts or expert consulting firms from the lists within 10 days if there is a reasonable basis for an objection and provide the updated lists to the affected utilities and other interested parties. If the Agency fails to remove an expert or expert consulting firm from a list, an objecting party may seek review by the Commission within 5 days thereafter by filing a petition, and the Commission shall render a ruling on the petition within 10 days. There is no right of appeal of the Commission's ruling.

(4) The Agency shall issue requests for proposals to the qualified experts or expert consulting firms to develop a procurement plan for the affected utilities and to serve as procurement administrator.

(5) The Agency shall select an expert or expert consulting firm to develop procurement plans based on the proposals submitted and shall award contracts of up to 5 years to those selected.

(6) The Agency shall select an expert or expert consulting firm, with approval of the Commission, to serve as procurement administrator based on the proposals submitted. If the Commission rejects, within 5 days, the Agency's selection, the Agency shall submit another recommendation within 3 days based on the proposals submitted. The Agency shall award a 5-year contract to the expert or expert consulting firm so selected with Commission approval.

(b) The experts or expert consulting firms retained by the Agency shall, as appropriate, prepare procurement plans, and conduct a competitive procurement process as prescribed in Section 16-111.5 of the Public Utilities Act, to ensure adequate, reliable, affordable, efficient, and environmentally sustainable electric service at the lowest total cost over time, taking into account any benefits of price stability, for eligible retail customers of electric utilities that on December 31, 2005 provided electric service to at least 100,000 customers in the State of Illinois, and for eligible Illinois retail customers of small multi-jurisdictional electric utilities that (i) on December 31, 2005 served less than 100,000 customers in Illinois and (ii) request a procurement plan for their Illinois jurisdictional load.

(c) Renewable portfolio standard.

(1)(A) The Agency shall develop a long-term renewable resources procurement plan that shall include procurement programs and competitive procurement events necessary to meet the goals set forth in this subsection (c). The initial long-term renewable resources procurement plan shall be released for comment no later than 160 days after June 1, 2017 (the effective date of Public Act 99-906). The Agency shall review, and may revise on an expedited basis, the long-term renewable resources procurement plan at least every 2 years, which shall be conducted in conjunction with the procurement plan under Section 16-111.5 of the Public Utilities Act to the extent practicable to minimize administrative expense. No later than 120 days after the effective date of this amendatory Act of the 103rd General Assembly, the Agency shall release for comment a revision to the long-term renewable resources procurement plan, updating elements of the most recently approved plan as needed to comply with this amendatory Act of the 103rd General Assembly, and any long-term renewable resources procurement plan update published by the Agency but not yet approved by the Illinois Commerce Commission shall be withdrawn. The long-term renewable resources procurement plans shall be subject to review and approval by the Commission under Section 16-111.5 of the Public Utilities Act.

(B) Subject to subparagraph (F) of this paragraph (1), the long-term renewable resources procurement plan shall attempt to meet the goals for procurement of renewable energy credits at levels of at least the following overall percentages: 13% by the 2017 delivery year; increasing by at least 1.5% each delivery year thereafter to at least 25% by the 2025 delivery year; increasing by at least 3% each delivery year thereafter to at least 40% by the 2030 delivery year, and continuing at no less than 40% for each delivery year thereafter. The Agency shall attempt to procure 50% by delivery year 2040. The Agency shall determine the annual increase between delivery year 2030 and delivery year 2040, if any, taking into account energy demand, other energy resources, and other public policy goals. In the event of a conflict between these goals and the new wind, new photovoltaic, and hydropower procurement requirements described in items (i) through (iii) of subparagraph (C) of this paragraph (1), the long-term plan shall prioritize compliance with the new wind, new photovoltaic, and hydropower procurement requirements described in items (i) through (iii) of subparagraph (C) of this paragraph (1) over the annual percentage targets described in this subparagraph (B). The Agency shall not comply with the annual percentage targets described in this subparagraph (B) by procuring renewable energy credits that are unlikely to lead to the development of new renewable resources or new, modernized, or retooled hydropower facilities.

For the delivery year beginning June 1, 2017, the procurement plan shall attempt to include, subject to the prioritization outlined in this subparagraph (B), cost-effective renewable energy resources equal to at least 13% of each utility's load for eligible retail customers and 13% of the applicable portion of each utility's load for retail customers who are not eligible retail customers, which applicable portion shall equal 50% of the utility's load for retail customers who are not eligible retail customers on February 28, 2017.

For the delivery year beginning June 1, 2018, the procurement plan shall attempt to include, subject to the prioritization outlined in this subparagraph (B), cost-effective renewable energy resources equal to at least 14.5% of each utility's load for eligible retail customers and 14.5% of the applicable portion of each utility's load for retail customers who are not eligible retail customers, which applicable portion shall equal 75% of the utility's load for retail customers who are not eligible retail customers on February 28, 2017.

For the delivery year beginning June 1, 2019, and for each year thereafter, the procurement plans shall attempt to include, subject to the prioritization outlined in this subparagraph (B), cost-effective renewable energy resources equal to a minimum percentage of each utility's load for all retail customers as follows: 16% by June 1, 2019; increasing by 1.5% each year thereafter to 25% by June 1, 2025; and 25% by June 1, 2026; increasing by at least 3% each delivery year thereafter to at least 40% by the 2030 delivery year, and continuing at no less than 40% for each delivery year thereafter. The Agency shall attempt to procure 50% by delivery year 2040. The Agency shall determine the annual increase between delivery year 2030 and delivery year 2040, if any, taking into account energy demand, other energy resources, and other public policy goals.

For each delivery year, the Agency shall first recognize each utility's obligations for that delivery year under existing contracts. Any renewable energy credits under existing contracts, including renewable energy credits as part of renewable energy resources, shall be used to meet the goals set forth in this subsection (c) for the delivery year.

(C) The long-term renewable resources procurement plan described in subparagraph (A) of this paragraph (1) shall include the procurement of renewable energy credits from new projects pursuant to the following terms:

(i) At least 10,000,000 renewable energy credits delivered annually by the end of the 2021 delivery year, and increasing ratably to reach 45,000,000 renewable energy credits delivered annually from new wind and solar projects, from repowered wind projects, or from retooled hydropower facilities by the end of delivery year 2030 such that the goals in subparagraph (B) of this paragraph (1) are met entirely by procurements of renewable energy credits from new wind and photovoltaic projects. Of that amount, to the extent possible, the Agency shall endeavor to procure 45% from new and repowered wind and hydropower projects and shall procure at least 55% from photovoltaic projects. Of the amount to be procured from photovoltaic projects, the Agency shall procure: at least 50% from solar photovoltaic projects using the program outlined in subparagraph (K) of this paragraph (1) from distributed renewable energy generation devices or community renewable generation projects; at least 47% from utility-scale solar projects; at least 3% from brownfield site photovoltaic projects that are not community renewable generation projects. The Agency may propose adjustments to these percentages, including establishing percentage-based goals for the procurement of renewable energy credits from modernized or retooled hydropower facilities and repowered wind projects, through its long-term renewable resources plan described in subparagraph (A) of this paragraph (1) as necessary based on developer interest, market conditions, budget considerations, resource adequacy needs, or other factors.

In developing the long-term renewable resources procurement plan, the Agency shall consider other approaches, in addition to competitive procurements, that can be used to procure renewable energy credits from brownfield site photovoltaic projects and thereby help return blighted or contaminated land to productive use while enhancing public health and the well-being of Illinois residents, including those in environmental justice communities, as defined using existing methodologies and findings used by the Agency and its Administrator in its Illinois Solar for All Program. The Agency shall also consider other approaches, in addition to competitive procurements, to procure renewable energy credits from new and existing hydropower facilities to support the development and maintenance of these facilities. The Agency shall explore options to convert existing dams but shall not consider approaches to develop new dams where they do not already exist. To encourage the continued operation of utility-scale wind projects, the Agency shall consider and may propose other approaches in addition to competitive procurements to procure renewable energy credits from repowered wind projects.

(ii) In any given delivery year, if forecasted expenses are less than the maximum budget available under subparagraph (E) of this paragraph (1), the Agency shall continue to procure new renewable energy credits until that budget is exhausted in the manner outlined in item (i) of this subparagraph (C).

(iii) For purposes of this Section:

"New wind projects" means wind renewable energy facilities that are energized after June 1, 2017 for the delivery year commencing June 1, 2017.

"New photovoltaic projects" means photovoltaic renewable energy facilities that are energized after June 1, 2017. Photovoltaic projects developed under Section 1-56 of this Act shall not apply towards the new photovoltaic project requirements in this subparagraph (C).

"Repowered wind projects" means utility-scale wind projects featuring the removal, replacement, or expansion of turbines at an existing project site, as defined in the long-term renewable resources procurement plan, after the effective date of this amendatory Act of the 103rd General Assembly. Renewable energy credit contract awards used to support repowered wind projects shall only cover the incremental increase in facility electricity production resultant from repowering.

For purposes of calculating whether the Agency has procured enough new wind and solar renewable energy credits required by this subparagraph (C), renewable energy facilities that have a multi-year renewable energy credit delivery contract with the utility through at least delivery year 2030 shall be considered new, however no renewable energy credits from contracts entered into before June 1, 2021 shall be used to calculate whether the Agency has procured the correct proportion of new wind and new solar contracts described in this subparagraph (C) for delivery year 2021 and thereafter.

(D) Renewable energy credits shall be cost effective. For purposes of this subsection (c), "cost effective" means that the costs of procuring renewable energy resources do not cause the limit stated in subparagraph (E) of this paragraph (1) to be exceeded and, for renewable energy credits procured through a competitive procurement event, do not exceed benchmarks based on market prices for like products in the region. For purposes of this subsection (c), "like products" means contracts for renewable energy credits from the same or substantially similar technology, same or substantially similar vintage (new or existing), the same or substantially similar quantity, and the same or substantially similar contract length and structure. Benchmarks shall reflect development, financing, or related costs resulting from requirements imposed through other provisions of State law, including, but not limited to, requirements in subparagraphs (P) and (Q) of this paragraph (1) and the Renewable Energy Facilities Agricultural Impact Mitigation Act. Confidential benchmarks shall be developed by the procurement administrator, in consultation with the Commission staff, Agency staff, and the procurement monitor and shall be subject to Commission review and approval. If price benchmarks for like products in the region are not available, the procurement administrator shall establish price benchmarks based on publicly available data on regional technology costs and expected current and future regional energy prices. The benchmarks in this Section shall not be used to curtail or otherwise reduce contractual obligations entered into by or through the Agency prior to June 1, 2017 (the effective date of Public Act 99-906).

(E) For purposes of this subsection (c), the required procurement of cost-effective renewable energy resources for a particular year commencing prior to June 1, 2017 shall be measured as a percentage of the actual amount of electricity (megawatt-hours) supplied by the electric utility to eligible retail customers in the delivery year ending immediately prior to the procurement, and, for delivery years commencing on and after June 1, 2017, the required procurement of cost-effective renewable energy resources for a particular year shall be measured as a percentage of the actual amount of electricity (megawatt-hours) delivered by the electric utility in the delivery year ending immediately prior to the procurement, to all retail customers in its service territory. For purposes of this subsection (c), the amount paid per kilowatthour means the total amount paid for electric service expressed on a per kilowatthour basis. For purposes of this subsection (c), the total amount paid for electric service includes without limitation amounts paid for supply, transmission, capacity, distribution, surcharges, and add-on taxes.

Notwithstanding the requirements of this subsection (c), and except as provided in subparagraph (E-5) of paragraph (1) of this subsection (c), the total of renewable energy resources procured under the procurement plan for any single year shall be subject to the limitations of this subparagraph (E). Such procurement shall be reduced for all retail customers based on the amount necessary to limit the annual estimated average net increase due to the costs of these resources included in the amounts paid by eligible retail customers in connection with electric service to no more than 4.25% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009. To arrive at a maximum dollar amount of renewable energy resources to be procured for the particular delivery year, the resulting per kilowatthour amount shall be applied to the actual amount of kilowatthours of electricity delivered, or applicable portion of such amount as specified in paragraph (1) of this subsection (c), as applicable, by the electric utility in the delivery year immediately prior to the procurement to all retail customers in its service territory. The calculations required by this subparagraph (E) shall be made only once for each delivery year at the time that the renewable energy resources are procured. Once the determination as to the amount of renewable energy resources to procure is made based on the calculations set forth in this subparagraph (E) and the contracts procuring those amounts are executed between the seller and applicable electric utility, no subsequent rate impact determinations shall be made and no adjustments to those contract amounts shall be allowed. As provided in subparagraph (E-5) of paragraph (1) of this subsection (c), the seller shall be entitled to full, prompt, and uninterrupted payment under the applicable contract notwithstanding the application of this subparagraph (E), and all All costs incurred under such contracts shall be fully recoverable by the electric utility as provided in this Section.

(E-5) If, for a particular delivery year, the limitation on the amount of renewable energy resources to be procured, as calculated pursuant to subparagraph (E) of paragraph (1) of this subsection (c), would result in an insufficient collection of funds to fully pay amounts due to a seller under existing contracts executed under this Section or executed under Section 1-56 of this Act, then the following provisions shall apply to ensure full and uninterrupted payment is made to such seller or sellers:

(i) If the electric utility has retained unspent funds in an interest-bearing account as prescribed in subsection (k) of Section 16-108 of the Public Utilities Act, then the utility shall use those funds to remit full payment to the sellers to ensure prompt and uninterrupted payment of existing contractual obligation.

(ii) If the funds described in item (i) of this subparagraph (E-5) are insufficient to satisfy all existing contractual obligations, then the electric utility shall, nonetheless, remit full payment to the sellers to ensure prompt and uninterrupted payment of existing contractual obligations, provided that the full costs shall be recoverable by the utility in accordance with part (ee) of item (iv) of this subsection (E-5).

(iii) The Agency shall promptly notify the Commission that existing contractual obligations are reasonably expected to exceed the maximum collection authorized under subparagraph (E) of paragraph (1) of this subsection (c) for the applicable delivery year. The Agency shall also explain and confirm how the operation of items (i) and (ii) of this subparagraph (E-5) ensures that the electric utility will continue to make prompt and uninterrupted payment under existing contractual obligations. The Agency shall provide this information to the Commission through a notice filed in the Commission docket approving the Agency's operative Long-Term Renewable Resources Procurement Plan that includes the applicable delivery year.

(iv) The Agency shall suspend or reduce new contract awards for the procurement of renewable energy credits until an Agency determination is made under subparagraph (E) that additional procurements would not cause the rate impact limitation of subparagraph (E) to be exceeded. At least once annually after the notice provided for in item (iii) of this subparagraph (E-5) is made, the Agency shall analyze existing contract obligations, projected prices for indexed renewable energy credit contracts executed under item (v) of subparagraph (G) of paragraph (1) of subsection (c) of Section 1-75 of this Act, and expected collections authorized under subparagraph (E) to determine whether and to what extent the limitations of subparagraph (E) would be exceeded by additional renewable energy credit procurement contract awards.

(aa) If the Agency determines that additional renewable energy credit procurement contract awards could be made without exceeding the limitations of subparagraph (E), then the procurements shall be authorized at a scale determined not to exceed the limitations of subparagraph (E) in a manner consistent with the priorities of this Section.

(bb) If the Agency determines that additional renewable energy credit procurement contract awards cannot be made without exceeding the limitations of subparagraph (E), then the Agency shall suspend any new contract awards for the procurement of renewable energy credits until a new rate impact determination is made under subparagraph (E).

(cc) Agency determinations made under this item (iv) shall be detailed and comprehensive and, if not made through the Agency's Long-Term Renewable Resources Procurement Plan, shall be filed as a compliance filing in the most recent docketed proceeding approving the Agency's Long-Term Renewable Resources Procurement Plan.

(dd) With respect to the procurement of renewable energy credits authorized through programs administered under subsection (b) of Section 1-56 and subparagraphs (K) through (M) of paragraph (1) of subsection (k) of Section 1-75 of this Act, the award of contracts for the procurement of renewable energy credits shall be suspended or reduced only at the conclusion of the program year in which the notice provided for under item (iii) of this subparagraph (E-5) is made.

(ee) The contract shall provide that, so long as at least one of: (i) the cost recovery mechanisms referenced in subsection (k) of Section 16-108 and subsection (l) of Section 16-111.5 of the Public Utilities Act remains in full force without limitation or (ii) the utility is otherwise authorized and or entitled to full, prompt, and uninterrupted recovery of its costs through any other mechanism, then such seller shall be entitled to full, prompt, and uninterrupted payment under the applicable contract notwithstanding the application of this subparagraph (E).

(F) If the limitation on the amount of renewable energy resources procured in subparagraph (E) of this paragraph (1) prevents the Agency from meeting all of the goals in this subsection (c), the Agency's long-term plan shall prioritize compliance with the requirements of this subsection (c) regarding renewable energy credits in the following order:

(i) renewable energy credits under existing contractual obligations as of June 1, 2021;

(i-5) funding for the Illinois Solar for All Program, as described in subparagraph (O) of this paragraph (1);

(ii) renewable energy credits necessary to comply with the new wind and new photovoltaic procurement requirements described in items (i) through (iii) of subparagraph (C) of this paragraph (1); and

(iii) renewable energy credits necessary to meet the remaining requirements of this subsection (c).

(G) The following provisions shall apply to the Agency's procurement of renewable energy credits under this subsection (c):

(i) Notwithstanding whether a long-term renewable resources procurement plan has been approved, the Agency shall conduct an initial forward procurement for renewable energy credits from new utility-scale wind projects within 160 days after June 1, 2017 (the effective date of Public Act 99-906). For the purposes of this initial forward procurement, the Agency shall solicit 15-year contracts for delivery of 1,000,000 renewable energy credits delivered annually from new utility-scale wind projects to begin delivery on June 1, 2019, if available, but not later than June 1, 2021, unless the project has delays in the establishment of an operating interconnection with the applicable transmission or distribution system as a result of the actions or inactions of the transmission or distribution provider, or other causes for force majeure as outlined in the procurement contract, in which case, not later than June 1, 2022. Payments to suppliers of renewable energy credits shall commence upon delivery. Renewable energy credits procured under this initial procurement shall be included in the Agency's long-term plan and shall apply to all renewable energy goals in this subsection (c).

(ii) Notwithstanding whether a long-term renewable resources procurement plan has been approved, the Agency shall conduct an initial forward procurement for renewable energy credits from new utility-scale solar projects and brownfield site photovoltaic projects within one year after June 1, 2017 (the effective date of Public Act 99-906). For the purposes of this initial forward procurement, the Agency shall solicit 15-year contracts for delivery of 1,000,000 renewable energy credits delivered annually from new utility-scale solar projects and brownfield site photovoltaic projects to begin delivery on June 1, 2019, if available, but not later than June 1, 2021, unless the project has delays in the establishment of an operating interconnection with the applicable transmission or distribution system as a result of the actions or inactions of the transmission or distribution provider, or other causes for force majeure as outlined in the procurement contract, in which case, not later than June 1, 2022. The Agency may structure this initial procurement in one or more discrete procurement events. Payments to suppliers of renewable energy credits shall commence upon delivery. Renewable energy credits procured under this initial procurement shall be included in the Agency's long-term plan and shall apply to all renewable energy goals in this subsection (c).

(iii) Notwithstanding whether the Commission has approved the periodic long-term renewable resources procurement plan revision described in Section 16-111.5 of the Public Utilities Act, the Agency shall conduct at least one subsequent forward procurement for renewable energy credits from new utility-scale wind projects, new utility-scale solar projects, and new brownfield site photovoltaic projects within 240 days after the effective date of this amendatory Act of the 102nd General Assembly in quantities necessary to meet the requirements of subparagraph (C) of this paragraph (1) through the delivery year beginning June 1, 2021.

(iv) Notwithstanding whether the Commission has approved the periodic long-term renewable resources procurement plan revision described in Section 16-111.5 of the Public Utilities Act, the Agency shall open capacity for each category in the Adjustable Block program within 90 days after the effective date of this amendatory Act of the 102nd General Assembly manner:

(1) The Agency shall open the first block of annual capacity for the category described in item (i) of subparagraph (K) of this paragraph (1). The first block of annual capacity for item (i) shall be for at least 75 megawatts of total nameplate capacity. The price of the renewable energy credit for this block of capacity shall be 4% less than the price of the last open block in this category. Projects on a waitlist shall be awarded contracts first in the order in which they appear on the waitlist. Notwithstanding anything to the contrary, for those renewable energy credits that qualify and are procured under this subitem (1) of this item (iv), the renewable energy credit delivery contract value shall be paid in full, based on the estimated generation during the first 15 years of operation, by the contracting utilities at the time that the facility producing the renewable energy credits is interconnected at the distribution system level of the utility and verified as energized and in compliance by the Program Administrator. The electric utility shall receive and retire all renewable energy credits generated by the project for the first 15 years of operation. Renewable energy credits generated by the project thereafter shall not be transferred under the renewable energy credit delivery contract with the counterparty electric utility.

(2) The Agency shall open the first block of annual capacity for the category described in item (ii) of subparagraph (K) of this paragraph (1). The first block of annual capacity for item (ii) shall be for at least 75 megawatts of total nameplate capacity.

(A) The price of the renewable energy credit for any project on a waitlist for this category before the opening of this block shall be 4% less than the price of the last open block in this category. Projects on the waitlist shall be awarded contracts first in the order in which they appear on the waitlist. Any projects that are less than or equal to 25 kilowatts in size on the waitlist for this capacity shall be moved to the waitlist for paragraph (1) of this item (iv). Notwithstanding anything to the contrary, projects that were on the waitlist prior to opening of this block shall not be required to be in compliance with the requirements of subparagraph (Q) of this paragraph (1) of this subsection (c). Notwithstanding anything to the contrary, for those renewable energy credits procured from projects that were on the waitlist for this category before the opening of this block 20% of the renewable energy credit delivery contract value, based on the estimated generation during the first 15 years of operation, shall be paid by the contracting utilities at the time that the facility producing the renewable energy credits is interconnected at the distribution system level of the utility and verified as energized by the Program Administrator. The remaining portion shall be paid ratably over the subsequent 4-year period. The electric utility shall receive and retire all renewable energy credits generated by the project during the first 15 years of operation. Renewable energy credits generated by the project thereafter shall not be transferred under the renewable energy credit delivery contract with the counterparty electric utility.

(B) The price of renewable energy credits for any project not on the waitlist for this category before the opening of the block shall be determined and published by the Agency. Projects not on a waitlist as of the opening of this block shall be subject to the requirements of subparagraph (Q) of this paragraph (1), as applicable. Projects not on a waitlist as of the opening of this block shall be subject to the contract provisions outlined in item (iii) of subparagraph (L) of this paragraph (1). The Agency shall strive to publish updated prices and an updated renewable energy credit delivery contract as quickly as possible.

(3) For opening the first 2 blocks of annual capacity for projects participating in item (iii) of subparagraph (K) of paragraph (1) of subsection (c), projects shall be selected exclusively from those projects on the ordinal waitlists of community renewable generation projects established by the Agency based on the status of those ordinal waitlists as of December 31, 2020, and only those projects previously determined to be eligible for the Agency's April 2019 community solar project selection process.

The first 2 blocks of annual capacity for item (iii) shall be for 250 megawatts of total nameplate capacity, with both blocks opening simultaneously under the schedule outlined in the paragraphs below. Projects shall be selected as follows:

(A) The geographic balance of selected projects shall follow the Group classification found in the Agency's Revised Long-Term Renewable Resources Procurement Plan, with 70% of capacity allocated to projects on the Group B waitlist and 30% of capacity allocated to projects on the Group A waitlist.

(B) Contract awards for waitlisted projects shall be allocated proportionate to the total nameplate capacity amount across both ordinal waitlists associated with that applicant firm or its affiliates, subject to the following conditions.

(i) Each applicant firm having a waitlisted project eligible for selection shall receive no less than 500 kilowatts in awarded capacity across all groups, and no approved vendor may receive more than 20% of each Group's waitlist allocation.

(ii) Each applicant firm, upon receiving an award of program capacity proportionate to its waitlisted capacity, may then determine which waitlisted projects it chooses to be selected for a contract award up to that capacity amount.

(iii) Assuming all other program requirements are met, applicant firms may adjust the nameplate capacity of applicant projects without losing waitlist eligibility, so long as no project is greater than 2,000 kilowatts in size.

(iv) Assuming all other program requirements are met, applicant firms may adjust the expected production associated with applicant projects, subject to verification by the Program Administrator.

(C) After a review of affiliate information and the current ordinal waitlists, the Agency shall announce the nameplate capacity award amounts associated with applicant firms no later than 90 days after the effective date of this amendatory Act of the 102nd General Assembly.

(D) Applicant firms shall submit their portfolio of projects used to satisfy those contract awards no less than 90 days after the Agency's announcement. The total nameplate capacity of all projects used to satisfy that portfolio shall be no greater than the Agency's nameplate capacity award amount associated with that applicant firm. An applicant firm may decline, in whole or in part, its nameplate capacity award without penalty, with such unmet capacity rolled over to the next block opening for project selection under item (iii) of subparagraph (K) of this subsection (c). Any projects not included in an applicant firm's portfolio may reapply without prejudice upon the next block reopening for project selection under item (iii) of subparagraph (K) of this subsection (c).

(E) The renewable energy credit delivery contract shall be subject to the contract and payment terms outlined in item (iv) of subparagraph (L) of this subsection (c). Contract instruments used for this subparagraph shall contain the following terms:

(i) Renewable energy credit prices shall be fixed, without further adjustment under any other provision of this Act or for any other reason, at 10% lower than prices applicable to the last open block for this category, inclusive of any adders available for achieving a minimum of 50% of subscribers to the project's nameplate capacity being residential or small commercial customers with subscriptions of below 25 kilowatts in size;

(ii) A requirement that a minimum of 50% of subscribers to the project's nameplate capacity be residential or small commercial customers with subscriptions of below 25 kilowatts in size;

(iii) Permission for the ability of a contract holder to substitute projects with other waitlisted projects without penalty should a project receive a non-binding estimate of costs to construct the interconnection facilities and any required distribution upgrades associated with that project of greater than 30 cents per watt AC of that project's nameplate capacity. In developing the applicable contract instrument, the Agency may consider whether other circumstances outside of the control of the applicant firm should also warrant project substitution rights.

The Agency shall publish a finalized updated renewable energy credit delivery contract developed consistent with these terms and conditions no less than 30 days before applicant firms must submit their portfolio of projects pursuant to item (D).

(F) To be eligible for an award, the applicant firm shall certify that not less than prevailing wage, as determined pursuant to the Illinois Prevailing Wage Act, was or will be paid to employees who are engaged in construction activities associated with a selected project.

(4) The Agency shall open the first block of annual capacity for the category described in item (iv) of subparagraph (K) of this paragraph (1). The first block of annual capacity for item (iv) shall be for at least 50 megawatts of total nameplate capacity. Renewable energy credit prices shall be fixed, without further adjustment under any other provision of this Act or for any other reason, at the price in the last open block in the category described in item (ii) of subparagraph (K) of this paragraph (1). Pricing for future blocks of annual capacity for this category may be adjusted in the Agency's second revision to its Long-Term Renewable Resources Procurement Plan. Projects in this category shall be subject to the contract terms outlined in item (iv) of subparagraph (L) of this paragraph (1).

(5) The Agency shall open the equivalent of 2 years of annual capacity for the category described in item (v) of subparagraph (K) of this paragraph (1). The first block of annual capacity for item (v) shall be for at least 10 megawatts of total nameplate capacity. Notwithstanding the provisions of item (v) of subparagraph (K) of this paragraph (1), for the purpose of this initial block, the agency shall accept new project applications intended to increase the diversity of areas hosting community solar projects, the business models of projects, and the size of projects, as described by the Agency in its long-term renewable resources procurement plan that is approved as of the effective date of this amendatory Act of the 102nd General Assembly. Projects in this category shall be subject to the contract terms outlined in item (iii) of subsection (L) of this paragraph (1).

(6) The Agency shall open the first blocks of annual capacity for the category described in item (vi) of subparagraph (K) of this paragraph (1), with allocations of capacity within the block generally matching the historical share of block capacity allocated between the category described in items (i) and (ii) of subparagraph (K) of this paragraph (1). The first two blocks of annual capacity for item (vi) shall be for at least 75 megawatts of total nameplate capacity. The price of renewable energy credits for the blocks of capacity shall be 4% less than the price of the last open blocks in the categories described in items (i) and (ii) of subparagraph (K) of this paragraph (1). Pricing for future blocks of annual capacity for this category may be adjusted in the Agency's second revision to its Long-Term Renewable Resources Procurement Plan. Projects in this category shall be subject to the applicable contract terms outlined in items (ii) and (iii) of subparagraph (L) of this paragraph (1).

(v) Upon the effective date of this amendatory Act of the 102nd General Assembly, for all competitive procurements and any procurements of renewable energy credit from new utility-scale wind and new utility-scale photovoltaic projects, the Agency shall procure indexed renewable energy credits and direct respondents to offer a strike price.

(1) The purchase price of the indexed renewable energy credit payment shall be calculated for each settlement period. That payment, for any settlement period, shall be equal to the difference resulting from subtracting the strike price from the index price for that settlement period. If this difference results in a negative number, the indexed REC counterparty shall owe the seller the absolute value multiplied by the quantity of energy produced in the relevant settlement period. If this difference results in a positive number, the seller shall owe the indexed REC counterparty this amount multiplied by the quantity of energy produced in the relevant settlement period.

(2) Parties shall cash settle every month, summing up all settlements (both positive and negative, if applicable) for the prior month.

(3) To ensure funding in the annual budget established under subparagraph (E) for indexed renewable energy credit procurements for each year of the term of such contracts, which must have a minimum tenure of 20 calendar years, the procurement administrator, Agency, Commission staff, and procurement monitor shall quantify the annual cost of the contract by utilizing an industry-standard, third-party forward price curve for energy at the appropriate hub or load zone, including the estimated magnitude and timing of the price effects related to federal carbon controls. Each forward price curve shall contain a specific value of the forecasted market price of electricity for each annual delivery year of the contract. For procurement planning purposes, the impact on the annual budget for the cost of indexed renewable energy credits for each delivery year shall be determined as the expected annual contract expenditure for that year, equaling the difference between (i) the sum across all relevant contracts of the applicable strike price multiplied by contract quantity and (ii) the sum across all relevant contracts of the forward price curve for the applicable load zone for that year multiplied by contract quantity. The contracting utility shall not assume an obligation in excess of the estimated annual cost of the contracts for indexed renewable energy credits. Forward curves shall be revised on an annual basis as updated forward price curves are released and filed with the Commission in the proceeding approving the Agency's most recent long-term renewable resources procurement plan. If the expected contract spend is higher or lower than the total quantity of contracts multiplied by the forward price curve value for that year, the forward price curve shall be updated by the procurement administrator, in consultation with the Agency, Commission staff, and procurement monitors, using then-currently available price forecast data and additional budget dollars shall be obligated or reobligated as appropriate.

(4) To ensure that indexed renewable energy credit prices remain predictable and affordable, the Agency may consider the institution of a price collar on REC prices paid under indexed renewable energy credit procurements establishing floor and ceiling REC prices applicable to indexed REC contract prices. Any price collars applicable to indexed REC procurements shall be proposed by the Agency through its long-term renewable resources procurement plan.

(vi) All procurements under this subparagraph (G), including the procurement of renewable energy credits from hydropower facilities, shall comply with the geographic requirements in subparagraph (I) of this paragraph (1) and shall follow the procurement processes and procedures described in this Section and Section 16-111.5 of the Public Utilities Act to the extent practicable, and these processes and procedures may be expedited to accommodate the schedule established by this subparagraph (G).

(vii) On and after the effective date of this amendatory Act of the 103rd General Assembly, for all procurements of renewable energy credits from hydropower facilities, the Agency shall establish contract terms designed to optimize existing hydropower facilities through modernization or retooling and establish new hydropower facilities at existing dams. Procurements made under this item (vii) shall prioritize projects located in designated environmental justice communities, as defined in subsection (b) of Section 1-56 of this Act, or in projects located in units of local government with median incomes that do not exceed 82% of the median income of the State.

(H) The procurement of renewable energy resources for a given delivery year shall be reduced as described in this subparagraph (H) if an alternative retail electric supplier meets the requirements described in this subparagraph (H).

(i) Within 45 days after June 1, 2017 (the effective date of Public Act 99-906), an alternative retail electric supplier or its successor shall submit an informational filing to the Illinois Commerce Commission certifying that, as of December 31, 2015, the alternative retail electric supplier owned one or more electric generating facilities that generates renewable energy resources as defined in Section 1-10 of this Act, provided that such facilities are not powered by wind or photovoltaics, and the facilities generate one renewable energy credit for each megawatthour of energy produced from the facility.

The informational filing shall identify each facility that was eligible to satisfy the alternative retail electric supplier's obligations under Section 16-115D of the Public Utilities Act as described in this item (i).

(ii) For a given delivery year, the alternative retail electric supplier may elect to supply its retail customers with renewable energy credits from the facility or facilities described in item (i) of this subparagraph (H) that continue to be owned by the alternative retail electric supplier.

(iii) The alternative retail electric supplier shall notify the Agency and the applicable utility, no later than February 28 of the year preceding the applicable delivery year or 15 days after June 1, 2017 (the effective date of Public Act 99-906), whichever is later, of its election under item (ii) of this subparagraph (H) to supply renewable energy credits to retail customers of the utility. Such election shall identify the amount of renewable energy credits to be supplied by the alternative retail electric supplier to the utility's retail customers and the source of the renewable energy credits identified in the informational filing as described in item (i) of this subparagraph (H), subject to the following limitations:

For the delivery year beginning June 1, 2018, the maximum amount of renewable energy credits to be supplied by an alternative retail electric supplier under this subparagraph (H) shall be 68% multiplied by 25% multiplied by 14.5% multiplied by the amount of metered electricity (megawatt-hours) delivered by the alternative retail electric supplier to Illinois retail customers during the delivery year ending May 31, 2016.

For delivery years beginning June 1, 2019 and each year thereafter, the maximum amount of renewable energy credits to be supplied by an alternative retail electric supplier under this subparagraph (H) shall be 68% multiplied by 50% multiplied by 16% multiplied by the amount of metered electricity (megawatt-hours) delivered by the alternative retail electric supplier to Illinois retail customers during the delivery year ending May 31, 2016, provided that the 16% value shall increase by 1.5% each delivery year thereafter to 25% by the delivery year beginning June 1, 2025, and thereafter the 25% value shall apply to each delivery year.

For each delivery year, the total amount of renewable energy credits supplied by all alternative retail electric suppliers under this subparagraph (H) shall not exceed 9% of the Illinois target renewable energy credit quantity. The Illinois target renewable energy credit quantity for the delivery year beginning June 1, 2018 is 14.5% multiplied by the total amount of metered electricity (megawatt-hours) delivered in the delivery year immediately preceding that delivery year, provided that the 14.5% shall increase by 1.5% each delivery year thereafter to 25% by the delivery year beginning June 1, 2025, and thereafter the 25% value shall apply to each delivery year.

If the requirements set forth in items (i) through (iii) of this subparagraph (H) are met, the charges that would otherwise be applicable to the retail customers of the alternative retail electric supplier under paragraph (6) of this subsection (c) for the applicable delivery year shall be reduced by the ratio of the quantity of renewable energy credits supplied by the alternative retail electric supplier compared to that supplier's target renewable energy credit quantity. The supplier's target renewable energy credit quantity for the delivery year beginning June 1, 2018 is 14.5% multiplied by the total amount of metered electricity (megawatt-hours) delivered by the alternative retail supplier in that delivery year, provided that the 14.5% shall increase by 1.5% each delivery year thereafter to 25% by the delivery year beginning June 1, 2025, and thereafter the 25% value shall apply to each delivery year.

On or before April 1 of each year, the Agency shall annually publish a report on its website that identifies the aggregate amount of renewable energy credits supplied by alternative retail electric suppliers under this subparagraph (H).

(I) The Agency shall design its long-term renewable energy procurement plan to maximize the State's interest in the health, safety, and welfare of its residents, including but not limited to minimizing sulfur dioxide, nitrogen oxide, particulate matter and other pollution that adversely affects public health in this State, increasing fuel and resource diversity in this State, enhancing the reliability and resiliency of the electricity distribution system in this State, meeting goals to limit carbon dioxide emissions under federal or State law, and contributing to a cleaner and healthier environment for the citizens of this State. In order to further these legislative purposes, renewable energy credits shall be eligible to be counted toward the renewable energy requirements of this subsection (c) if they are generated from facilities located in this State. The Agency may qualify renewable energy credits from facilities located in states adjacent to Illinois or renewable energy credits associated with the electricity generated by a utility-scale wind energy facility or utility-scale photovoltaic facility and transmitted by a qualifying direct current project described in subsection (b-5) of Section 8-406 of the Public Utilities Act to a delivery point on the electric transmission grid located in this State or a state adjacent to Illinois, if the generator demonstrates and the Agency determines that the operation of such facility or facilities will help promote the State's interest in the health, safety, and welfare of its residents based on the public interest criteria described above. For the purposes of this Section, renewable resources that are delivered via a high voltage direct current converter station located in Illinois shall be deemed generated in Illinois at the time and location the energy is converted to alternating current by the high voltage direct current converter station if the high voltage direct current transmission line: (i) after the effective date of this amendatory Act of the 102nd General Assembly, was constructed with a project labor agreement; (ii) is capable of transmitting electricity at 525kv; (iii) has an Illinois converter station located and interconnected in the region of the PJM Interconnection, LLC; (iv) does not operate as a public utility; and (v) if the high voltage direct current transmission line was energized after June 1, 2023. To ensure that the public interest criteria are applied to the procurement and given full effect, the Agency's long-term procurement plan shall describe in detail how each public interest factor shall be considered and weighted for facilities located in states adjacent to Illinois.

(J) In order to promote the competitive development of renewable energy resources in furtherance of the State's interest in the health, safety, and welfare of its residents, renewable energy credits shall not be eligible to be counted toward the renewable energy requirements of this subsection (c) if they are sourced from a generating unit whose costs were being recovered through rates regulated by this State or any other state or states on or after January 1, 2017. Each contract executed to purchase renewable energy credits under this subsection (c) shall provide for the contract's termination if the costs of the generating unit supplying the renewable energy credits subsequently begin to be recovered through rates regulated by this State or any other state or states; and each contract shall further provide that, in that event, the supplier of the credits must return 110% of all payments received under the contract. Amounts returned under the requirements of this subparagraph (J) shall be retained by the utility and all of these amounts shall be used for the procurement of additional renewable energy credits from new wind or new photovoltaic resources as defined in this subsection (c). The long-term plan shall provide that these renewable energy credits shall be procured in the next procurement event.

Notwithstanding the limitations of this subparagraph (J), renewable energy credits sourced from generating units that are constructed, purchased, owned, or leased by an electric utility as part of an approved project, program, or pilot under Section 1-56 of this Act shall be eligible to be counted toward the renewable energy requirements of this subsection (c), regardless of how the costs of these units are recovered. As long as a generating unit or an identifiable portion of a generating unit has not had and does not have its costs recovered through rates regulated by this State or any other state, HVDC renewable energy credits associated with that generating unit or identifiable portion thereof shall be eligible to be counted toward the renewable energy requirements of this subsection (c).

(K) The long-term renewable resources procurement plan developed by the Agency in accordance with subparagraph (A) of this paragraph (1) shall include an Adjustable Block program for the procurement of renewable energy credits from new photovoltaic projects that are distributed renewable energy generation devices or new photovoltaic community renewable generation projects. The Adjustable Block program shall be generally designed to provide for the steady, predictable, and sustainable growth of new solar photovoltaic development in Illinois. To this end, the Adjustable Block program shall provide a transparent annual schedule of prices and quantities to enable the photovoltaic market to scale up and for renewable energy credit prices to adjust at a predictable rate over time. The prices set by the Adjustable Block program can be reflected as a set value or as the product of a formula.

The Adjustable Block program shall include for each category of eligible projects for each delivery year: a single block of nameplate capacity, a price for renewable energy credits within that block, and the terms and conditions for securing a spot on a waitlist once the block is fully committed or reserved. Except as outlined below, the waitlist of projects in a given year will carry over to apply to the subsequent year when another block is opened. Only projects energized on or after June 1, 2017 shall be eligible for the Adjustable Block program. For each category for each delivery year the Agency shall determine the amount of generation capacity in each block, and the purchase price for each block, provided that the purchase price provided and the total amount of generation in all blocks for all categories shall be sufficient to meet the goals in this subsection (c). The Agency shall strive to issue a single block sized to provide for stability and market growth. The Agency shall establish program eligibility requirements that ensure that projects that enter the program are sufficiently mature to indicate a demonstrable path to completion. The Agency may periodically review its prior decisions establishing the amount of generation capacity in each block, and the purchase price for each block, and may propose, on an expedited basis, changes to these previously set values, including but not limited to redistributing these amounts and the available funds as necessary and appropriate, subject to Commission approval as part of the periodic plan revision process described in Section 16-111.5 of the Public Utilities Act. The Agency may define different block sizes, purchase prices, or other distinct terms and conditions for projects located in different utility service territories if the Agency deems it necessary to meet the goals in this subsection (c).

The Adjustable Block program shall include the following categories in at least the following amounts:

(i) At least 20% from distributed renewable energy generation devices with a nameplate capacity of no more than 25 kilowatts.

(ii) At least 20% from distributed renewable energy generation devices with a nameplate capacity of more than 25 kilowatts and no more than 5,000 kilowatts. The Agency may create sub-categories within this category to account for the differences between projects for small commercial customers, large commercial customers, and public or non-profit customers.

(iii) At least 30% from photovoltaic community renewable generation projects. Capacity for this category for the first 2 delivery years after the effective date of this amendatory Act of the 102nd General Assembly shall be allocated to waitlist projects as provided in paragraph (3) of item (iv) of subparagraph (G). Starting in the third delivery year after the effective date of this amendatory Act of the 102nd General Assembly or earlier if the Agency determines there is additional capacity needed for to meet previous delivery year requirements, the following shall apply:

(1) the Agency shall select projects on a first-come, first-serve basis, however the Agency may suggest additional methods to prioritize projects that are submitted at the same time;

(2) projects shall have subscriptions of 25 kW or less for at least 50% of the facility's nameplate capacity and the Agency shall price the renewable energy credits with that as a factor;

(3) projects shall not be colocated with one or more other community renewable generation projects, as defined in the Agency's first revised long-term renewable resources procurement plan approved by the Commission on February 18, 2020, such that the aggregate nameplate capacity exceeds 5,000 kilowatts; and

(4) projects greater than 2 MW may not apply until after the approval of the Agency's revised Long-Term Renewable Resources Procurement Plan after the effective date of this amendatory Act of the 102nd General Assembly.

(iv) At least 15% from distributed renewable generation devices or photovoltaic community renewable generation projects installed on public school land. The Agency may create subcategories within this category to account for the differences between project size or location. Projects located within environmental justice communities or within Organizational Units that fall within Tier 1 or Tier 2 shall be given priority. Each of the Agency's periodic updates to its long-term renewable resources procurement plan to incorporate the procurement described in this subparagraph (iv) shall also include the proposed quantities or blocks, pricing, and contract terms applicable to the procurement as indicated herein. In each such update and procurement, the Agency shall set the renewable energy credit price and establish payment terms for the renewable energy credits procured pursuant to this subparagraph (iv) that make it feasible and affordable for public schools to install photovoltaic distributed renewable energy devices on their premises, including, but not limited to, those public schools subject to the prioritization provisions of this subparagraph. For the purposes of this item (iv):

"Environmental Justice Community" shall have the same meaning set forth in the Agency's long-term renewable resources procurement plan;

"Organization Unit", "Tier 1" and "Tier 2" shall have the meanings set for in Section 18-8.15 of the School Code;

"Public schools" shall have the meaning set forth in Section 1-3 of the School Code and includes public institutions of higher education, as defined in the Board of Higher Education Act.

(v) At least 5% from community-driven community solar projects intended to provide more direct and tangible connection and benefits to the communities which they serve or in which they operate and, additionally, to increase the variety of community solar locations, models, and options in Illinois. As part of its long-term renewable resources procurement plan, the Agency shall develop selection criteria for projects participating in this category. Nothing in this Section shall preclude the Agency from creating a selection process that maximizes community ownership and community benefits in selecting projects to receive renewable energy credits. Selection criteria shall include:

(1) community ownership or community wealth-building;

(2) additional direct and indirect community benefit, beyond project participation as a subscriber, including, but not limited to, economic, environmental, social, cultural, and physical benefits;

(3) meaningful involvement in project organization and development by community members or nonprofit organizations or public entities located in or serving the community;

(4) engagement in project operations and management by nonprofit organizations, public entities, or community members; and

(5) whether a project is developed in response to a site-specific RFP developed by community members or a nonprofit organization or public entity located in or serving the community.

Selection criteria may also prioritize projects that:

(1) are developed in collaboration with or to provide complementary opportunities for the Clean Jobs Workforce Network Program, the Illinois Climate Works Preapprenticeship Program, the Returning Residents Clean Jobs Training Program, the Clean Energy Contractor Incubator Program, or the Clean Energy Primes Contractor Accelerator Program;

(2) increase the diversity of locations of community solar projects in Illinois, including by locating in urban areas and population centers;

(3) are located in Equity Investment Eligible Communities;

(4) are not greenfield projects;

(5) serve only local subscribers;

(6) have a nameplate capacity that does not exceed 500 kW;

(7) are developed by an equity eligible contractor; or

(8) otherwise meaningfully advance the goals of providing more direct and tangible connection and benefits to the communities which they serve or in which they operate and increasing the variety of community solar locations, models, and options in Illinois.

For the purposes of this item (v):

"Community" means a social unit in which people come together regularly to effect change; a social unit in which participants are marked by a cooperative spirit, a common purpose, or shared interests or characteristics; or a space understood by its residents to be delineated through geographic boundaries or landmarks.

"Community benefit" means a range of services and activities that provide affirmative, economic, environmental, social, cultural, or physical value to a community; or a mechanism that enables economic development, high-quality employment, and education opportunities for local workers and residents, or formal monitoring and oversight structures such that community members may ensure that those services and activities respond to local knowledge and needs.

"Community ownership" means an arrangement in which an electric generating facility is, or over time will be, in significant part, owned collectively by members of the community to which an electric generating facility provides benefits; members of that community participate in decisions regarding the governance, operation, maintenance, and upgrades of and to that facility; and members of that community benefit from regular use of that facility.

Terms and guidance within these criteria that are not defined in this item (v) shall be defined by the Agency, with stakeholder input, during the development of the Agency's long-term renewable resources procurement plan. The Agency shall develop regular opportunities for projects to submit applications for projects under this category, and develop selection criteria that gives preference to projects that better meet individual criteria as well as projects that address a higher number of criteria.

(vi) At least 10% from distributed renewable energy generation devices, which includes distributed renewable energy devices with a nameplate capacity under 5,000 kilowatts or photovoltaic community renewable generation projects, from applicants that are equity eligible contractors. The Agency may create subcategories within this category to account for the differences between project size and type. The Agency shall propose to increase the percentage in this item (vi) over time to 40% based on factors, including, but not limited to, the number of equity eligible contractors and capacity used in this item (vi) in previous delivery years.

The Agency shall propose a payment structure for contracts executed pursuant to this paragraph under which, upon a demonstration of qualification or need, applicant firms are advanced capital disbursed after contract execution but before the contracted project's energization. The amount or percentage of capital advanced prior to project energization shall be sufficient to both cover any increase in development costs resulting from prevailing wage requirements or project-labor agreements, and designed to overcome barriers in access to capital faced by equity eligible contractors. The amount or percentage of advanced capital may vary by subcategory within this category and by an applicant's demonstration of need, with such levels to be established through the Long-Term Renewable Resources Procurement Plan authorized under subparagraph (A) of paragraph (1) of subsection (c) of this Section.

Contracts developed featuring capital advanced prior to a project's energization shall feature provisions to ensure both the successful development of applicant projects and the delivery of the renewable energy credits for the full term of the contract, including ongoing collateral requirements and other provisions deemed necessary by the Agency, and may include energization timelines longer than for comparable project types. The percentage or amount of capital advanced prior to project energization shall not operate to increase the overall contract value, however contracts executed under this subparagraph may feature renewable energy credit prices higher than those offered to similar projects participating in other categories. Capital advanced prior to energization shall serve to reduce the ratable payments made after energization under items (ii) and (iii) of subparagraph (L) or payments made for each renewable energy credit delivery under item (iv) of subparagraph (L).

(vii) The remaining capacity shall be allocated by the Agency in order to respond to market demand. The Agency shall allocate any discretionary capacity prior to the beginning of each delivery year.

To the extent there is uncontracted capacity from any block in any of categories (i) through (vi) at the end of a delivery year, the Agency shall redistribute that capacity to one or more other categories giving priority to categories with projects on a waitlist. The redistributed capacity shall be added to the annual capacity in the subsequent delivery year, and the price for renewable energy credits shall be the price for the new delivery year. Redistributed capacity shall not be considered redistributed when determining whether the goals in this subsection (K) have been met.

Notwithstanding anything to the contrary, as the Agency increases the capacity in item (vi) to 40% over time, the Agency may reduce the capacity of items (i) through (v) proportionate to the capacity of the categories of projects in item (vi), to achieve a balance of project types.

The Adjustable Block program shall be designed to ensure that renewable energy credits are procured from projects in diverse locations and are not concentrated in a few regional areas.

(L) Notwithstanding provisions for advancing capital prior to project energization found in item (vi) of subparagraph (K), the procurement of photovoltaic renewable energy credits under items (i) through (vi) of subparagraph (K) of this paragraph (1) shall otherwise be subject to the following contract and payment terms:

(i) (Blank).

(ii) For those renewable energy credits that qualify and are procured under item (i) of subparagraph (K) of this paragraph (1), and any similar category projects that are procured under item (vi) of subparagraph (K) of this paragraph (1) that qualify and are procured under item (vi), the contract length shall be 15 years. The renewable energy credit delivery contract value shall be paid in full, based on the estimated generation during the first 15 years of operation, by the contracting utilities at the time that the facility producing the renewable energy credits is interconnected at the distribution system level of the utility and verified as energized and compliant by the Program Administrator. The electric utility shall receive and retire all renewable energy credits generated by the project for the first 15 years of operation. Renewable energy credits generated by the project thereafter shall not be transferred under the renewable energy credit delivery contract with the counterparty electric utility.

(iii) For those renewable energy credits that qualify and are procured under item (ii) and (v) of subparagraph (K) of this paragraph (1) and any like projects similar category that qualify and are procured under item (vi), the contract length shall be 15 years. 15% of the renewable energy credit delivery contract value, based on the estimated generation during the first 15 years of operation, shall be paid by the contracting utilities at the time that the facility producing the renewable energy credits is interconnected at the distribution system level of the utility and verified as energized and compliant by the Program Administrator. The remaining portion shall be paid ratably over the subsequent 6-year period. The electric utility shall receive and retire all renewable energy credits generated by the project for the first 15 years of operation. Renewable energy credits generated by the project thereafter shall not be transferred under the renewable energy credit delivery contract with the counterparty electric utility.

(iv) For those renewable energy credits that qualify and are procured under items (iii) and (iv) of subparagraph (K) of this paragraph (1), and any like projects that qualify and are procured under item (vi), the renewable energy credit delivery contract length shall be 20 years and shall be paid over the delivery term, not to exceed during each delivery year the contract price multiplied by the estimated annual renewable energy credit generation amount. If generation of renewable energy credits during a delivery year exceeds the estimated annual generation amount, the excess renewable energy credits shall be carried forward to future delivery years and shall not expire during the delivery term. If generation of renewable energy credits during a delivery year, including carried forward excess renewable energy credits, if any, is less than the estimated annual generation amount, payments during such delivery year will not exceed the quantity generated plus the quantity carried forward multiplied by the contract price. The electric utility shall receive all renewable energy credits generated by the project during the first 20 years of operation and retire all renewable energy credits paid for under this item (iv) and return at the end of the delivery term all renewable energy credits that were not paid for. Renewable energy credits generated by the project thereafter shall not be transferred under the renewable energy credit delivery contract with the counterparty electric utility. Notwithstanding the preceding, for those projects participating under item (iii) of subparagraph (K), the contract price for a delivery year shall be based on subscription levels as measured on the higher of the first business day of the delivery year or the first business day 6 months after the first business day of the delivery year. Subscription of 90% of nameplate capacity or greater shall be deemed to be fully subscribed for the purposes of this item (iv). For projects receiving a 20-year delivery contract, REC prices shall be adjusted downward for consistency with the incentive levels previously determined to be necessary to support projects under 15-year delivery contracts, taking into consideration any additional new requirements placed on the projects, including, but not limited to, labor standards.

(v) Each contract shall include provisions to ensure the delivery of the estimated quantity of renewable energy credits and ongoing collateral requirements and other provisions deemed appropriate by the Agency.

(vi) The utility shall be the counterparty to the contracts executed under this subparagraph (L) that are approved by the Commission under the process described in Section 16-111.5 of the Public Utilities Act. No contract shall be executed for an amount that is less than one renewable energy credit per year.

(vii) If, at any time, approved applications for the Adjustable Block program exceed funds collected by the electric utility or would cause the Agency to exceed the limitation described in subparagraph (E) of this paragraph (1) on the amount of renewable energy resources that may be procured, then the Agency may consider future uncommitted funds to be reserved for these contracts on a first-come, first-served basis.

(viii) Nothing in this Section shall require the utility to advance any payment or pay any amounts that exceed the actual amount of revenues anticipated to be collected by the utility under paragraph (6) of this subsection (c) and subsection (k) of Section 16-108 of the Public Utilities Act inclusive of eligible funds collected in prior years and alternative compliance payments for use by the utility, and contracts executed under this Section shall expressly incorporate this limitation.

(ix) Notwithstanding other requirements of this subparagraph (L), no modification shall be required to Adjustable Block program contracts if they were already executed prior to the establishment, approval, and implementation of new contract forms as a result of this amendatory Act of the 102nd General Assembly.

(x) Contracts may be assignable, but only to entities first deemed by the Agency to have met program terms and requirements applicable to direct program participation. In developing contracts for the delivery of renewable energy credits, the Agency shall be permitted to establish fees applicable to each contract assignment.

(M) The Agency shall be authorized to retain one or more experts or expert consulting firms to develop, administer, implement, operate, and evaluate the Adjustable Block program described in subparagraph (K) of this paragraph (1), and the Agency shall retain the consultant or consultants in the same manner, to the extent practicable, as the Agency retains others to administer provisions of this Act, including, but not limited to, the procurement administrator. The selection of experts and expert consulting firms and the procurement process described in this subparagraph (M) are exempt from the requirements of Section 20-10 of the Illinois Procurement Code, under Section 20-10 of that Code. The Agency shall strive to minimize administrative expenses in the implementation of the Adjustable Block program.

The Program Administrator may charge application fees to participating firms to cover the cost of program administration. Any application fee amounts shall initially be determined through the long-term renewable resources procurement plan, and modifications to any application fee that deviate more than 25% from the Commission's approved value must be approved by the Commission as a long-term plan revision under Section 16-111.5 of the Public Utilities Act. The Agency shall consider stakeholder feedback when making adjustments to application fees and shall notify stakeholders in advance of any planned changes.

In addition to covering the costs of program administration, the Agency, in conjunction with its Program Administrator, may also use the proceeds of such fees charged to participating firms to support public education and ongoing regional and national coordination with nonprofit organizations, public bodies, and others engaged in the implementation of renewable energy incentive programs or similar initiatives. This work may include developing papers and reports, hosting regional and national conferences, and other work deemed necessary by the Agency to position the State of Illinois as a national leader in renewable energy incentive program development and administration.

The Agency and its consultant or consultants shall monitor block activity, share program activity with stakeholders and conduct quarterly meetings to discuss program activity and market conditions. If necessary, the Agency may make prospective administrative adjustments to the Adjustable Block program design, such as making adjustments to purchase prices as necessary to achieve the goals of this subsection (c). Program modifications to any block price that do not deviate from the Commission's approved value by more than 10% shall take effect immediately and are not subject to Commission review and approval. Program modifications to any block price that deviate more than 10% from the Commission's approved value must be approved by the Commission as a long-term plan amendment under Section 16-111.5 of the Public Utilities Act. The Agency shall consider stakeholder feedback when making adjustments to the Adjustable Block design and shall notify stakeholders in advance of any planned changes.

The Agency and its program administrators for both the Adjustable Block program and the Illinois Solar for All Program, consistent with the requirements of this subsection (c) and subsection (b) of Section 1-56 of this Act, shall propose the Adjustable Block program terms, conditions, and requirements, including the prices to be paid for renewable energy credits, where applicable, and requirements applicable to participating entities and project applications, through the development, review, and approval of the Agency's long-term renewable resources procurement plan described in this subsection (c) and paragraph (5) of subsection (b) of Section 16-111.5 of the Public Utilities Act. Terms, conditions, and requirements for program participation shall include the following:

(i) The Agency shall establish a registration process for entities seeking to qualify for program-administered incentive funding and establish baseline qualifications for vendor approval. The Agency must maintain a list of approved entities on each program's website, and may revoke a vendor's ability to receive program-administered incentive funding status upon a determination that the vendor failed to comply with contract terms, the law, or other program requirements.

(ii) The Agency shall establish program requirements and minimum contract terms to ensure projects are properly installed and produce their expected amounts of energy. Program requirements may include on-site inspections and photo documentation of projects under construction. The Agency may require repairs, alterations, or additions to remedy any material deficiencies discovered. Vendors who have a disproportionately high number of deficient systems may lose their eligibility to continue to receive State-administered incentive funding through Agency programs and procurements.

(iii) To discourage deceptive marketing or other bad faith business practices, the Agency may require direct program participants, including agents operating on their behalf, to provide standardized disclosures to a customer prior to that customer's execution of a contract for the development of a distributed generation system or a subscription to a community solar project.

(iv) The Agency shall establish one or multiple Consumer Complaints Centers to accept complaints regarding businesses that participate in, or otherwise benefit from, State-administered incentive funding through Agency-administered programs. The Agency shall maintain a public database of complaints with any confidential or particularly sensitive information redacted from public entries.

(v) Through a filing in the proceeding for the approval of its long-term renewable energy resources procurement plan, the Agency shall provide an annual written report to the Illinois Commerce Commission documenting the frequency and nature of complaints and any enforcement actions taken in response to those complaints.

(vi) The Agency shall schedule regular meetings with representatives of the Office of the Attorney General, the Illinois Commerce Commission, consumer protection groups, and other interested stakeholders to share relevant information about consumer protection, project compliance, and complaints received.

(vii) To the extent that complaints received implicate the jurisdiction of the Office of the Attorney General, the Illinois Commerce Commission, or local, State, or federal law enforcement, the Agency shall also refer complaints to those entities as appropriate.

(N) The Agency shall establish the terms, conditions, and program requirements for photovoltaic community renewable generation projects with a goal to expand access to a broader group of energy consumers, to ensure robust participation opportunities for residential and small commercial customers and those who cannot install renewable energy on their own properties. Subject to reasonable limitations, any plan approved by the Commission shall allow subscriptions to community renewable generation projects to be portable and transferable. For purposes of this subparagraph (N), "portable" means that subscriptions may be retained by the subscriber even if the subscriber relocates or changes its address within the same utility service territory; and "transferable" means that a subscriber may assign or sell subscriptions to another person within the same utility service territory.

Through the development of its long-term renewable resources procurement plan, the Agency may consider whether community renewable generation projects utilizing technologies other than photovoltaics should be supported through State-administered incentive funding, and may issue requests for information to gauge market demand.

Electric utilities shall provide a monetary credit to a subscriber's subsequent bill for service for the proportional output of a community renewable generation project attributable to that subscriber as specified in Section 16-107.5 of the Public Utilities Act.

The Agency shall purchase renewable energy credits from subscribed shares of photovoltaic community renewable generation projects through the Adjustable Block program described in subparagraph (K) of this paragraph (1) or through the Illinois Solar for All Program described in Section 1-56 of this Act. The electric utility shall purchase any unsubscribed energy from community renewable generation projects that are Qualifying Facilities ("QF") under the electric utility's tariff for purchasing the output from QFs under Public Utilities Regulatory Policies Act of 1978.

The owners of and any subscribers to a community renewable generation project shall not be considered public utilities or alternative retail electricity suppliers under the Public Utilities Act solely as a result of their interest in or subscription to a community renewable generation project and shall not be required to become an alternative retail electric supplier by participating in a community renewable generation project with a public utility.

(O) For the delivery year beginning June 1, 2018, the long-term renewable resources procurement plan required by this subsection (c) shall provide for the Agency to procure contracts to continue offering the Illinois Solar for All Program described in subsection (b) of Section 1-56 of this Act, and the contracts approved by the Commission shall be executed by the utilities that are subject to this subsection (c). The long-term renewable resources procurement plan shall allocate up to $50,000,000 per delivery year to fund the programs, and the plan shall determine the amount of funding to be apportioned to the programs identified in subsection (b) of Section 1-56 of this Act; provided that for the delivery years beginning June 1, 2021, June 1, 2022, and June 1, 2023, the long-term renewable resources procurement plan may average the annual budgets over a 3-year period to account for program ramp-up. For the delivery years beginning June 1, 2021, June 1, 2024, June 1, 2027, and June 1, 2030 and additional $10,000,000 shall be provided to the Department of Commerce and Economic Opportunity to implement the workforce development programs and reporting as outlined in Section 16-108.12 of the Public Utilities Act. In making the determinations required under this subparagraph (O), the Commission shall consider the experience and performance under the programs and any evaluation reports. The Commission shall also provide for an independent evaluation of those programs on a periodic basis that are funded under this subparagraph (O).

(P) All programs and procurements under this subsection (c) shall be designed to encourage participating projects to use a diverse and equitable workforce and a diverse set of contractors, including minority-owned businesses, disadvantaged businesses, trade unions, graduates of any workforce training programs administered under this Act, and small businesses.

The Agency shall develop a method to optimize procurement of renewable energy credits from proposed utility-scale projects that are located in communities eligible to receive Energy Transition Community Grants pursuant to Section 10-20 of the Energy Community Reinvestment Act. If this requirement conflicts with other provisions of law or the Agency determines that full compliance with the requirements of this subparagraph (P) would be unreasonably costly or administratively impractical, the Agency is to propose alternative approaches to achieve development of renewable energy resources in communities eligible to receive Energy Transition Community Grants pursuant to Section 10-20 of the Energy Community Reinvestment Act or seek an exemption from this requirement from the Commission.

(Q) Each facility listed in subitems (i) through (ix) of item (1) of this subparagraph (Q) for which a renewable energy credit delivery contract is signed after the effective date of this amendatory Act of the 102nd General Assembly is subject to the following requirements through the Agency's long-term renewable resources procurement plan:

(1) Each facility shall be subject to the prevailing wage requirements included in the Prevailing Wage Act. The Agency shall require verification that all construction performed on the facility by the renewable energy credit delivery contract holder, its contractors, or its subcontractors relating to construction of the facility is performed by construction employees receiving an amount for that work equal to or greater than the general prevailing rate, as that term is defined in Section 3 of the Prevailing Wage Act. For purposes of this item (1), "house of worship" means property that is both (1) used exclusively by a religious society or body of persons as a place for religious exercise or religious worship and (2) recognized as exempt from taxation pursuant to Section 15-40 of the Property Tax Code. This item (1) shall apply to any the following:

(i) all new utility-scale wind projects;

(ii) all new utility-scale photovoltaic projects and repowered wind projects;

(iii) all new brownfield photovoltaic projects;

(iv) all new photovoltaic community renewable energy facilities that qualify for item (iii) of subparagraph (K) of this paragraph (1);

(v) all new community driven community photovoltaic projects that qualify for item (v) of subparagraph (K) of this paragraph (1);

(vi) all new photovoltaic projects on public school land that qualify for item (iv) of subparagraph (K) of this paragraph (1);

(vii) all new photovoltaic distributed renewable energy generation devices that (1) qualify for item (i) of subparagraph (K) of this paragraph (1); (2) are not projects that serve single-family or multi-family residential buildings; and (3) are not houses of worship where the aggregate capacity including collocated projects would not exceed 100 kilowatts;

(viii) all new photovoltaic distributed renewable energy generation devices that (1) qualify for item (ii) of subparagraph (K) of this paragraph (1); (2) are not projects that serve single-family or multi-family residential buildings; and (3) are not houses of worship where the aggregate capacity including collocated projects would not exceed 100 kilowatts;

(ix) all new, modernized, or retooled hydropower facilities.

(2) Renewable energy credits procured from new utility-scale wind projects, new utility-scale solar projects, and new brownfield solar projects, repowered wind projects, and retooled hydropower facilities pursuant to Agency procurement events occurring after the effective date of this amendatory Act of the 102nd General Assembly must be from facilities built by general contractors that must enter into a project labor agreement, as defined by this Act, prior to construction. The project labor agreement shall be filed with the Director in accordance with procedures established by the Agency through its long-term renewable resources procurement plan. Any information submitted to the Agency in this item (2) shall be considered commercially sensitive information. At a minimum, the project labor agreement must provide the names, addresses, and occupations of the owner of the plant and the individuals representing the labor organization employees participating in the project labor agreement consistent with the Project Labor Agreements Act. The agreement must also specify the terms and conditions as defined by this Act.

(3) It is the intent of this Section to ensure that economic development occurs across Illinois communities, that emerging businesses may grow, and that there is improved access to the clean energy economy by persons who have greater economic burdens to success. The Agency shall take into consideration the unique cost of compliance of this subparagraph (Q) that might be borne by equity eligible contractors, shall include such costs when determining the price of renewable energy credits in the Adjustable Block program, and shall take such costs into consideration in a nondiscriminatory manner when comparing bids for competitive procurements. The Agency shall consider costs associated with compliance whether in the development, financing, or construction of projects. The Agency shall periodically review the assumptions in these costs and may adjust prices, in compliance with subparagraph (M) of this paragraph (1).

(R) In its long-term renewable resources procurement plan, the Agency shall establish a self-direct renewable portfolio standard compliance program for eligible self-direct customers that purchase renewable energy credits from utility-scale wind and solar projects through long-term agreements for purchase of renewable energy credits as described in this Section. Such long-term agreements may include the purchase of energy or other products on a physical or financial basis and may involve an alternative retail electric supplier as defined in Section 16-102 of the Public Utilities Act. This program shall take effect in the delivery year commencing June 1, 2023.

(1) For the purposes of this subparagraph:

"Eligible self-direct customer" means any retail customers of an electric utility that serves 3,000,000 or more retail customers in the State and whose total highest 30-minute demand was more than 10,000 kilowatts, or any retail customers of an electric utility that serves less than 3,000,000 retail customers but more than 500,000 retail customers in the State and whose total highest 15-minute demand was more than 10,000 kilowatts.

"Retail customer" has the meaning set forth in Section 16-102 of the Public Utilities Act and multiple retail customer accounts under the same corporate parent may aggregate their account demands to meet the 10,000 kilowatt threshold. The criteria for determining whether this subparagraph is applicable to a retail customer shall be based on the 12 consecutive billing periods prior to the start of the year in which the application is filed.

(2) For renewable energy credits to count toward the self-direct renewable portfolio standard compliance program, they must:

(i) qualify as renewable energy credits as defined in Section 1-10 of this Act;

(ii) be sourced from one or more renewable energy generating facilities that comply with the geographic requirements as set forth in subparagraph (I) of paragraph (1) of subsection (c) as interpreted through the Agency's long-term renewable resources procurement plan, or, where applicable, the geographic requirements that governed utility-scale renewable energy credits at the time the eligible self-direct customer entered into the applicable renewable energy credit purchase agreement;

(iii) be procured through long-term contracts with term lengths of at least 10 years either directly with the renewable energy generating facility or through a bundled power purchase agreement, a virtual power purchase agreement, an agreement between the renewable generating facility, an alternative retail electric supplier, and the customer, or such other structure as is permissible under this subparagraph (R);

(iv) be equivalent in volume to at least 40% of the eligible self-direct customer's usage, determined annually by the eligible self-direct customer's usage during the previous delivery year, measured to the nearest megawatt-hour;

(v) be retired by or on behalf of the large energy customer;

(vi) be sourced from new utility-scale wind projects or new utility-scale solar projects; and

(vii) if the contracts for renewable energy credits are entered into after the effective date of this amendatory Act of the 102nd General Assembly, the new utility-scale wind projects or new utility-scale solar projects must comply with the requirements established in subparagraphs (P) and (Q) of paragraph (1) of this subsection (c) and subsection (c-10).

(3) The self-direct renewable portfolio standard compliance program shall be designed to allow eligible self-direct customers to procure new renewable energy credits from new utility-scale wind projects or new utility-scale photovoltaic projects. The Agency shall annually determine the amount of utility-scale renewable energy credits it will include each year from the self-direct renewable portfolio standard compliance program, subject to receiving qualifying applications. In making this determination, the Agency shall evaluate publicly available analyses and studies of the potential market size for utility-scale renewable energy long-term purchase agreements by commercial and industrial energy customers and make that report publicly available. If demand for participation in the self-direct renewable portfolio standard compliance program exceeds availability, the Agency shall ensure participation is evenly split between commercial and industrial users to the extent there is sufficient demand from both customer classes. Each renewable energy credit procured pursuant to this subparagraph (R) by a self-direct customer shall reduce the total volume of renewable energy credits the Agency is otherwise required to procure from new utility-scale projects pursuant to subparagraph (C) of paragraph (1) of this subsection (c) on behalf of contracting utilities where the eligible self-direct customer is located. The self-direct customer shall file an annual compliance report with the Agency pursuant to terms established by the Agency through its long-term renewable resources procurement plan to be eligible for participation in this program. Customers must provide the Agency with their most recent electricity billing statements or other information deemed necessary by the Agency to demonstrate they are an eligible self-direct customer.

(4) The Commission shall approve a reduction in the volumetric charges collected pursuant to Section 16-108 of the Public Utilities Act for approved eligible self-direct customers equivalent to the anticipated cost of renewable energy credit deliveries under contracts for new utility-scale wind and new utility-scale solar entered for each delivery year after the large energy customer begins retiring eligible new utility scale renewable energy credits for self-compliance. The self-direct credit amount shall be determined annually and is equal to the estimated portion of the cost authorized by subparagraph (E) of paragraph (1) of this subsection (c) that supported the annual procurement of utility-scale renewable energy credits in the prior delivery year using a methodology described in the long-term renewable resources procurement plan, expressed on a per kilowatthour basis, and does not include (i) costs associated with any contracts entered into before the delivery year in which the customer files the initial compliance report to be eligible for participation in the self-direct program, and (ii) costs associated with procuring renewable energy credits through existing and future contracts through the Adjustable Block Program, subsection (c-5) of this Section 1-75, and the Solar for All Program. The Agency shall assist the Commission in determining the current and future costs. The Agency must determine the self-direct credit amount for new and existing eligible self-direct customers and submit this to the Commission in an annual compliance filing. The Commission must approve the self-direct credit amount by June 1, 2023 and June 1 of each delivery year thereafter.

(5) Customers described in this subparagraph (R) shall apply, on a form developed by the Agency, to the Agency to be designated as a self-direct eligible customer. Once the Agency determines that a self-direct customer is eligible for participation in the program, the self-direct customer will remain eligible until the end of the term of the contract. Thereafter, application may be made not less than 12 months before the filing date of the long-term renewable resources procurement plan described in this Act. At a minimum, such application shall contain the following:

(i) the customer's certification that, at the time of the customer's application, the customer qualifies to be a self-direct eligible customer, including documents demonstrating that qualification;

(ii) the customer's certification that the customer has entered into or will enter into by the beginning of the applicable procurement year, one or more bilateral contracts for new wind projects or new photovoltaic projects, including supporting documentation;

(iii) certification that the contract or contracts for new renewable energy resources are long-term contracts with term lengths of at least 10 years, including supporting documentation;

(iv) certification of the quantities of renewable energy credits that the customer will purchase each year under such contract or contracts, including supporting documentation;

(v) proof that the contract is sufficient to produce renewable energy credits to be equivalent in volume to at least 40% of the large energy customer's usage from the previous delivery year, measured to the nearest megawatt-hour; and

(vi) certification that the customer intends to maintain the contract for the duration of the length of the contract.

(6) If a customer receives the self-direct credit but fails to properly procure and retire renewable energy credits as required under this subparagraph (R), the Commission, on petition from the Agency and after notice and hearing, may direct such customer's utility to recover the cost of the wrongfully received self-direct credits plus interest through an adder to charges assessed pursuant to Section 16-108 of the Public Utilities Act. Self-direct customers who knowingly fail to properly procure and retire renewable energy credits and do not notify the Agency are ineligible for continued participation in the self-direct renewable portfolio standard compliance program.

(2) (Blank).

(3) (Blank).

(4) The electric utility shall retire all renewable energy credits used to comply with the standard.

(5) Beginning with the 2010 delivery year and ending June 1, 2017, an electric utility subject to this subsection (c) shall apply the lesser of the maximum alternative compliance payment rate or the most recent estimated alternative compliance payment rate for its service territory for the corresponding compliance period, established pursuant to subsection (d) of Section 16-115D of the Public Utilities Act to its retail customers that take service pursuant to the electric utility's hourly pricing tariff or tariffs. The electric utility shall retain all amounts collected as a result of the application of the alternative compliance payment rate or rates to such customers, and, beginning in 2011, the utility shall include in the information provided under item (1) of subsection (d) of Section 16-111.5 of the Public Utilities Act the amounts collected under the alternative compliance payment rate or rates for the prior year ending May 31. Notwithstanding any limitation on the procurement of renewable energy resources imposed by item (2) of this subsection (c), the Agency shall increase its spending on the purchase of renewable energy resources to be procured by the electric utility for the next plan year by an amount equal to the amounts collected by the utility under the alternative compliance payment rate or rates in the prior year ending May 31.

(6) The electric utility shall be entitled to recover all of its costs associated with the procurement of renewable energy credits under plans approved under this Section and Section 16-111.5 of the Public Utilities Act. These costs shall include associated reasonable expenses for implementing the procurement programs, including, but not limited to, the costs of administering and evaluating the Adjustable Block program, through an automatic adjustment clause tariff in accordance with subsection (k) of Section 16-108 of the Public Utilities Act.

(7) Renewable energy credits procured from new photovoltaic projects or new distributed renewable energy generation devices under this Section after June 1, 2017 (the effective date of Public Act 99-906) must be procured from devices installed by a qualified person in compliance with the requirements of Section 16-128A of the Public Utilities Act and any rules or regulations adopted thereunder.

In meeting the renewable energy requirements of this subsection (c), to the extent feasible and consistent with State and federal law, the renewable energy credit procurements, Adjustable Block solar program, and community renewable generation program shall provide employment opportunities for all segments of the population and workforce, including minority-owned and female-owned business enterprises, and shall not, consistent with State and federal law, discriminate based on race or socioeconomic status.

(c-5) Procurement of renewable energy credits from new renewable energy facilities installed at or adjacent to the sites of electric generating facilities that burn or burned coal as their primary fuel source.

(1) In addition to the procurement of renewable energy credits pursuant to long-term renewable resources procurement plans in accordance with subsection (c) of this Section and Section 16-111.5 of the Public Utilities Act, the Agency shall conduct procurement events in accordance with this subsection (c-5) for the procurement by electric utilities that served more than 300,000 retail customers in this State as of January 1, 2019 of renewable energy credits from new renewable energy facilities to be installed at or adjacent to the sites of electric generating facilities that, as of January 1, 2016, burned coal as their primary fuel source and meet the other criteria specified in this subsection (c-5). For purposes of this subsection (c-5), "new renewable energy facility" means a new utility-scale solar project as defined in this Section 1-75. The renewable energy credits procured pursuant to this subsection (c-5) may be included or counted for purposes of compliance with the amounts of renewable energy credits required to be procured pursuant to subsection (c) of this Section to the extent that there are otherwise shortfalls in compliance with such requirements. The procurement of renewable energy credits by electric utilities pursuant to this subsection (c-5) shall be funded solely by revenues collected from the Coal to Solar and Energy Storage Initiative Charge provided for in this subsection (c-5) and subsection (i-5) of Section 16-108 of the Public Utilities Act, shall not be funded by revenues collected through any of the other funding mechanisms provided for in subsection (c) of this Section, and shall not be subject to the limitation imposed by subsection (c) on charges to retail customers for costs to procure renewable energy resources pursuant to subsection (c), and shall not be subject to any other requirements or limitations of subsection (c).

(2) The Agency shall conduct 2 procurement events to select owners of electric generating facilities meeting the eligibility criteria specified in this subsection (c-5) to enter into long-term contracts to sell renewable energy credits to electric utilities serving more than 300,000 retail customers in this State as of January 1, 2019. The first procurement event shall be conducted no later than March 31, 2022, unless the Agency elects to delay it, until no later than May 1, 2022, due to its overall volume of work, and shall be to select owners of electric generating facilities located in this State and south of federal Interstate Highway 80 that meet the eligibility criteria specified in this subsection (c-5). The second procurement event shall be conducted no sooner than September 30, 2022 and no later than October 31, 2022 and shall be to select owners of electric generating facilities located anywhere in this State that meet the eligibility criteria specified in this subsection (c-5). The Agency shall establish and announce a time period, which shall begin no later than 30 days prior to the scheduled date for the procurement event, during which applicants may submit applications to be selected as suppliers of renewable energy credits pursuant to this subsection (c-5). The eligibility criteria for selection as a supplier of renewable energy credits pursuant to this subsection (c-5) shall be as follows:

(A) The applicant owns an electric generating facility located in this State that: (i) as of January 1, 2016, burned coal as its primary fuel to generate electricity; and (ii) has, or had prior to retirement, an electric generating capacity of at least 150 megawatts. The electric generating facility can be either: (i) retired as of the date of the procurement event; or (ii) still operating as of the date of the procurement event.

(B) The applicant is not (i) an electric cooperative as defined in Section 3-119 of the Public Utilities Act, or (ii) an entity described in subsection (b)(1) of Section 3-105 of the Public Utilities Act, or an association or consortium of or an entity owned by entities described in (i) or (ii); and the coal-fueled electric generating facility was at one time owned, in whole or in part, by a public utility as defined in Section 3-105 of the Public Utilities Act.

(C) If participating in the first procurement event, the applicant proposes and commits to construct and operate, at the site, and if necessary for sufficient space on property adjacent to the existing property, at which the electric generating facility identified in paragraph (A) is located: (i) a new renewable energy facility of at least 20 megawatts but no more than 100 megawatts of electric generating capacity, and (ii) an energy storage facility having a storage capacity equal to at least 2 megawatts and at most 10 megawatts. If participating in the second procurement event, the applicant proposes and commits to construct and operate, at the site, and if necessary for sufficient space on property adjacent to the existing property, at which the electric generating facility identified in paragraph (A) is located: (i) a new renewable energy facility of at least 5 megawatts but no more than 20 megawatts of electric generating capacity, and (ii) an energy storage facility having a storage capacity equal to at least 0.5 megawatts and at most one megawatt.

(D) The applicant agrees that the new renewable energy facility and the energy storage facility will be constructed or installed by a qualified entity or entities in compliance with the requirements of subsection (g) of Section 16-128A of the Public Utilities Act and any rules adopted thereunder.

(E) The applicant agrees that personnel operating the new renewable energy facility and the energy storage facility will have the requisite skills, knowledge, training, experience, and competence, which may be demonstrated by completion or current participation and ultimate completion by employees of an accredited or otherwise recognized apprenticeship program for the employee's particular craft, trade, or skill, including through training and education courses and opportunities offered by the owner to employees of the coal-fueled electric generating facility or by previous employment experience performing the employee's particular work skill or function.

(F) The applicant commits that not less than the prevailing wage, as determined pursuant to the Prevailing Wage Act, will be paid to the applicant's employees engaged in construction activities associated with the new renewable energy facility and the new energy storage facility and to the employees of applicant's contractors engaged in construction activities associated with the new renewable energy facility and the new energy storage facility, and that, on or before the commercial operation date of the new renewable energy facility, the applicant shall file a report with the Agency certifying that the requirements of this subparagraph (F) have been met.

(G) The applicant commits that if selected, it will negotiate a project labor agreement for the construction of the new renewable energy facility and associated energy storage facility that includes provisions requiring the parties to the agreement to work together to establish diversity threshold requirements and to ensure best efforts to meet diversity targets, improve diversity at the applicable job site, create diverse apprenticeship opportunities, and create opportunities to employ former coal-fired power plant workers.

(H) The applicant commits to enter into a contract or contracts for the applicable duration to provide specified numbers of renewable energy credits each year from the new renewable energy facility to electric utilities that served more than 300,000 retail customers in this State as of January 1, 2019, at a price of $30 per renewable energy credit. The price per renewable energy credit shall be fixed at $30 for the applicable duration and the renewable energy credits shall not be indexed renewable energy credits as provided for in item (v) of subparagraph (G) of paragraph (1) of subsection (c) of Section 1-75 of this Act. The applicable duration of each contract shall be 20 years, unless the applicant is physically interconnected to the PJM Interconnection, LLC transmission grid and had a generating capacity of at least 1,200 megawatts as of January 1, 2021, in which case the applicable duration of the contract shall be 15 years.

(I) The applicant's application is certified by an officer of the applicant and by an officer of the applicant's ultimate parent company, if any.

(3) An applicant may submit applications to contract to supply renewable energy credits from more than one new renewable energy facility to be constructed at or adjacent to one or more qualifying electric generating facilities owned by the applicant. The Agency may select new renewable energy facilities to be located at or adjacent to the sites of more than one qualifying electric generation facility owned by an applicant to contract with electric utilities to supply renewable energy credits from such facilities.

(4) The Agency shall assess fees to each applicant to recover the Agency's costs incurred in receiving and evaluating applications, conducting the procurement event, developing contracts for sale, delivery and purchase of renewable energy credits, and monitoring the administration of such contracts, as provided for in this subsection (c-5), including fees paid to a procurement administrator retained by the Agency for one or more of these purposes.

(5) The Agency shall select the applicants and the new renewable energy facilities to contract with electric utilities to supply renewable energy credits in accordance with this subsection (c-5). In the first procurement event, the Agency shall select applicants and new renewable energy facilities to supply renewable energy credits, at a price of $30 per renewable energy credit, aggregating to no less than 400,000 renewable energy credits per year for the applicable duration, assuming sufficient qualifying applications to supply, in the aggregate, at least that amount of renewable energy credits per year; and not more than 580,000 renewable energy credits per year for the applicable duration. In the second procurement event, the Agency shall select applicants and new renewable energy facilities to supply renewable energy credits, at a price of $30 per renewable energy credit, aggregating to no more than 625,000 renewable energy credits per year less the amount of renewable energy credits each year contracted for as a result of the first procurement event, for the applicable durations. The number of renewable energy credits to be procured as specified in this paragraph (5) shall not be reduced based on renewable energy credits procured in the self-direct renewable energy credit compliance program established pursuant to subparagraph (R) of paragraph (1) of subsection (c) of Section 1-75.

(6) The obligation to purchase renewable energy credits from the applicants and their new renewable energy facilities selected by the Agency shall be allocated to the electric utilities based on their respective percentages of kilowatthours delivered to delivery services customers to the aggregate kilowatthour deliveries by the electric utilities to delivery services customers for the year ended December 31, 2021. In order to achieve these allocation percentages between or among the electric utilities, the Agency shall require each applicant that is selected in the procurement event to enter into a contract with each electric utility for the sale and purchase of renewable energy credits from each new renewable energy facility to be constructed and operated by the applicant, with the sale and purchase obligations under the contracts to aggregate to the total number of renewable energy credits per year to be supplied by the applicant from the new renewable energy facility.

(7) The Agency shall submit its proposed selection of applicants, new renewable energy facilities to be constructed, and renewable energy credit amounts for each procurement event to the Commission for approval. The Commission shall, within 2 business days after receipt of the Agency's proposed selections, approve the proposed selections if it determines that the applicants and the new renewable energy facilities to be constructed meet the selection criteria set forth in this subsection (c-5) and that the Agency seeks approval for contracts of applicable durations aggregating to no more than the maximum amount of renewable energy credits per year authorized by this subsection (c-5) for the procurement event, at a price of $30 per renewable energy credit.

(8) The Agency, in conjunction with its procurement administrator if one is retained, the electric utilities, and potential applicants for contracts to produce and supply renewable energy credits pursuant to this subsection (c-5), shall develop a standard form contract for the sale, delivery and purchase of renewable energy credits pursuant to this subsection (c-5). Each contract resulting from the first procurement event shall allow for a commercial operation date for the new renewable energy facility of either June 1, 2023 or June 1, 2024, with such dates subject to adjustment as provided in this paragraph. Each contract resulting from the second procurement event shall provide for a commercial operation date on June 1 next occurring up to 48 months after execution of the contract. Each contract shall provide that the owner shall receive payments for renewable energy credits for the applicable durations beginning with the commercial operation date of the new renewable energy facility. The form contract shall provide for adjustments to the commercial operation and payment start dates as needed due to any delays in completing the procurement and contracting processes, in finalizing interconnection agreements and installing interconnection facilities, and in obtaining other necessary governmental permits and approvals. The form contract shall be, to the maximum extent possible, consistent with standard electric industry contracts for sale, delivery, and purchase of renewable energy credits while taking into account the specific requirements of this subsection (c-5). The form contract shall provide for over-delivery and under-delivery of renewable energy credits within reasonable ranges during each 12-month period and penalty, default, and enforcement provisions for failure of the selling party to deliver renewable energy credits as specified in the contract and to comply with the requirements of this subsection (c-5). The standard form contract shall specify that all renewable energy credits delivered to the electric utility pursuant to the contract shall be retired. The Agency shall make the proposed contracts available for a reasonable period for comment by potential applicants, and shall publish the final form contract at least 30 days before the date of the first procurement event.

(9) Coal to Solar and Energy Storage Initiative Charge.

(A) By no later than July 1, 2022, each electric utility that served more than 300,000 retail customers in this State as of January 1, 2019 shall file a tariff with the Commission for the billing and collection of a Coal to Solar and Energy Storage Initiative Charge in accordance with subsection (i-5) of Section 16-108 of the Public Utilities Act, with such tariff to be effective, following review and approval or modification by the Commission, beginning January 1, 2023. The tariff shall provide for the calculation and setting of the electric utility's Coal to Solar and Energy Storage Initiative Charge to collect revenues estimated to be sufficient, in the aggregate, (i) to enable the electric utility to pay for the renewable energy credits it has contracted to purchase in the delivery year beginning June 1, 2023 and each delivery year thereafter from new renewable energy facilities located at the sites of qualifying electric generating facilities, and (ii) to fund the grant payments to be made in each delivery year by the Department of Commerce and Economic Opportunity, or any successor department or agency, which shall be referred to in this subsection (c-5) as the Department, pursuant to paragraph (10) of this subsection (c-5). The electric utility's tariff shall provide for the billing and collection of the Coal to Solar and Energy Storage Initiative Charge on each kilowatthour of electricity delivered to its delivery services customers within its service territory and shall provide for an annual reconciliation of revenues collected with actual costs, in accordance with subsection (i-5) of Section 16-108 of the Public Utilities Act.

(B) Each electric utility shall remit on a monthly basis to the State Treasurer, for deposit in the Coal to Solar and Energy Storage Initiative Fund provided for in this subsection (c-5), the electric utility's collections of the Coal to Solar and Energy Storage Initiative Charge in the amount estimated to be needed by the Department for grant payments pursuant to grant contracts entered into by the Department pursuant to paragraph (10) of this subsection (c-5).

(10) Coal to Solar and Energy Storage Initiative Fund.

(A) The Coal to Solar and Energy Storage Initiative Fund is established as a special fund in the State treasury. The Coal to Solar and Energy Storage Initiative Fund is authorized to receive, by statutory deposit, that portion specified in item (B) of paragraph (9) of this subsection (c-5) of moneys collected by electric utilities through imposition of the Coal to Solar and Energy Storage Initiative Charge required by this subsection (c-5). The Coal to Solar and Energy Storage Initiative Fund shall be administered by the Department to provide grants to support the installation and operation of energy storage facilities at the sites of qualifying electric generating facilities meeting the criteria specified in this paragraph (10).

(B) The Coal to Solar and Energy Storage Initiative Fund shall not be subject to sweeps, administrative charges, or chargebacks, including, but not limited to, those authorized under Section 8h of the State Finance Act, that would in any way result in the transfer of those funds from the Coal to Solar and Energy Storage Initiative Fund to any other fund of this State or in having any such funds utilized for any purpose other than the express purposes set forth in this paragraph (10).

(C) The Department shall utilize up to $280,500,000 in the Coal to Solar and Energy Storage Initiative Fund for grants, assuming sufficient qualifying applicants, to support installation of energy storage facilities at the sites of up to 3 qualifying electric generating facilities located in the Midcontinent Independent System Operator, Inc., region in Illinois and the sites of up to 2 qualifying electric generating facilities located in the PJM Interconnection, LLC region in Illinois that meet the criteria set forth in this subparagraph (C). The criteria for receipt of a grant pursuant to this subparagraph (C) are as follows:

(1) the electric generating facility at the site has, or had prior to retirement, an electric generating capacity of at least 150 megawatts;

(2) the electric generating facility burns (or burned prior to retirement) coal as its primary source of fuel;

(3) if the electric generating facility is retired, it was retired subsequent to January 1, 2016;

(4) the owner of the electric generating facility has not been selected by the Agency pursuant to this subsection (c-5) of this Section to enter into a contract to sell renewable energy credits to one or more electric utilities from a new renewable energy facility located or to be located at or adjacent to the site at which the electric generating facility is located;

(5) the electric generating facility located at the site was at one time owned, in whole or in part, by a public utility as defined in Section 3-105 of the Public Utilities Act;

(6) the electric generating facility at the site is not owned by (i) an electric cooperative as defined in Section 3-119 of the Public Utilities Act, or (ii) an entity described in subsection (b)(1) of Section 3-105 of the Public Utilities Act, or an association or consortium of or an entity owned by entities described in items (i) or (ii);

(7) the proposed energy storage facility at the site will have energy storage capacity of at least 37 megawatts;

(8) the owner commits to place the energy storage facility into commercial operation on either June 1, 2023, June 1, 2024, or June 1, 2025, with such date subject to adjustment as needed due to any delays in completing the grant contracting process, in finalizing interconnection agreements and in installing interconnection facilities, and in obtaining necessary governmental permits and approvals;

(9) the owner agrees that the new energy storage facility will be constructed or installed by a qualified entity or entities consistent with the requirements of subsection (g) of Section 16-128A of the Public Utilities Act and any rules adopted under that Section;

(10) the owner agrees that personnel operating the energy storage facility will have the requisite skills, knowledge, training, experience, and competence, which may be demonstrated by completion or current participation and ultimate completion by employees of an accredited or otherwise recognized apprenticeship program for the employee's particular craft, trade, or skill, including through training and education courses and opportunities offered by the owner to employees of the coal-fueled electric generating facility or by previous employment experience performing the employee's particular work skill or function;

(11) the owner commits that not less than the prevailing wage, as determined pursuant to the Prevailing Wage Act, will be paid to the owner's employees engaged in construction activities associated with the new energy storage facility and to the employees of the owner's contractors engaged in construction activities associated with the new energy storage facility, and that, on or before the commercial operation date of the new energy storage facility, the owner shall file a report with the Department certifying that the requirements of this subparagraph (11) have been met; and

(12) the owner commits that if selected to receive a grant, it will negotiate a project labor agreement for the construction of the new energy storage facility that includes provisions requiring the parties to the agreement to work together to establish diversity threshold requirements and to ensure best efforts to meet diversity targets, improve diversity at the applicable job site, create diverse apprenticeship opportunities, and create opportunities to employ former coal-fired power plant workers.

The Department shall accept applications for this grant program until March 31, 2022 and shall announce the award of grants no later than June 1, 2022. The Department shall make the grant payments to a recipient in equal annual amounts for 10 years following the date the energy storage facility is placed into commercial operation. The annual grant payments to a qualifying energy storage facility shall be $110,000 per megawatt of energy storage capacity, with total annual grant payments pursuant to this subparagraph (C) for qualifying energy storage facilities not to exceed $28,050,000 in any year.

(D) Grants of funding for energy storage facilities pursuant to subparagraph (C) of this paragraph (10), from the Coal to Solar and Energy Storage Initiative Fund, shall be memorialized in grant contracts between the Department and the recipient. The grant contracts shall specify the date or dates in each year on which the annual grant payments shall be paid.

(E) All disbursements from the Coal to Solar and Energy Storage Initiative Fund shall be made only upon warrants of the Comptroller drawn upon the Treasurer as custodian of the Fund upon vouchers signed by the Director of the Department or by the person or persons designated by the Director of the Department for that purpose. The Comptroller is authorized to draw the warrants upon vouchers so signed. The Treasurer shall accept all written warrants so signed and shall be released from liability for all payments made on those warrants.

(11) Diversity, equity, and inclusion plans.

(A) Each applicant selected in a procurement event to contract to supply renewable energy credits in accordance with this subsection (c-5) and each owner selected by the Department to receive a grant or grants to support the construction and operation of a new energy storage facility or facilities in accordance with this subsection (c-5) shall, within 60 days following the Commission's approval of the applicant to contract to supply renewable energy credits or within 60 days following execution of a grant contract with the Department, as applicable, submit to the Commission a diversity, equity, and inclusion plan setting forth the applicant's or owner's numeric goals for the diversity composition of its supplier entities for the new renewable energy facility or new energy storage facility, as applicable, which shall be referred to for purposes of this paragraph (11) as the project, and the applicant's or owner's action plan and schedule for achieving those goals.

(B) For purposes of this paragraph (11), diversity composition shall be based on the percentage, which shall be a minimum of 25%, of eligible expenditures for contract awards for materials and services (which shall be defined in the plan) to business enterprises owned by minority persons, women, or persons with disabilities as defined in Section 2 of the Business Enterprise for Minorities, Women, and Persons with Disabilities Act, to LGBTQ business enterprises, to veteran-owned business enterprises, and to business enterprises located in environmental justice communities. The diversity composition goals of the plan may include eligible expenditures in areas for vendor or supplier opportunities in addition to development and construction of the project, and may exclude from eligible expenditures materials and services with limited market availability, limited production and availability from suppliers in the United States, such as solar panels and storage batteries, and material and services that are subject to critical energy infrastructure or cybersecurity requirements or restrictions. The plan may provide that the diversity composition goals may be met through Tier 1 Direct or Tier 2 subcontracting expenditures or a combination thereof for the project.

(C) The plan shall provide for, but not be limited to: (i) internal initiatives, including multi-tier initiatives, by the applicant or owner, or by its engineering, procurement and construction contractor if one is used for the project, which for purposes of this paragraph (11) shall be referred to as the EPC contractor, to enable diverse businesses to be considered fairly for selection to provide materials and services; (ii) requirements for the applicant or owner or its EPC contractor to proactively solicit and utilize diverse businesses to provide materials and services; and (iii) requirements for the applicant or owner or its EPC contractor to hire a diverse workforce for the project. The plan shall include a description of the applicant's or owner's diversity recruiting efforts both for the project and for other areas of the applicant's or owner's business operations. The plan shall provide for the imposition of financial penalties on the applicant's or owner's EPC contractor for failure to exercise best efforts to comply with and execute the EPC contractor's diversity obligations under the plan. The plan may provide for the applicant or owner to set aside a portion of the work on the project to serve as an incubation program for qualified businesses, as specified in the plan, owned by minority persons, women, persons with disabilities, LGBTQ persons, and veterans, and businesses located in environmental justice communities, seeking to enter the renewable energy industry.

(D) The applicant or owner may submit a revised or updated plan to the Commission from time to time as circumstances warrant. The applicant or owner shall file annual reports with the Commission detailing the applicant's or owner's progress in implementing its plan and achieving its goals and any modifications the applicant or owner has made to its plan to better achieve its diversity, equity and inclusion goals. The applicant or owner shall file a final report on the fifth June 1 following the commercial operation date of the new renewable energy resource or new energy storage facility, but the applicant or owner shall thereafter continue to be subject to applicable reporting requirements of Section 5-117 of the Public Utilities Act.

(c-10) Equity accountability system. It is the purpose of this subsection (c-10) to create an equity accountability system, which includes the minimum equity standards for all renewable energy procurements, the equity category of the Adjustable Block Program, and the equity prioritization for noncompetitive procurements, that is successful in advancing priority access to the clean energy economy for businesses and workers from communities that have been excluded from economic opportunities in the energy sector, have been subject to disproportionate levels of pollution, and have disproportionately experienced negative public health outcomes. Further, it is the purpose of this subsection to ensure that this equity accountability system is successful in advancing equity across Illinois by providing access to the clean energy economy for businesses and workers from communities that have been historically excluded from economic opportunities in the energy sector, have been subject to disproportionate levels of pollution, and have disproportionately experienced negative public health outcomes.

(1) Minimum equity standards. The Agency shall create programs with the purpose of increasing access to and development of equity eligible contractors, who are prime contractors and subcontractors, across all of the programs it manages. All applications for renewable energy credit procurements shall comply with specific minimum equity commitments. Starting in the delivery year immediately following the next long-term renewable resources procurement plan, at least 10% of the project workforce for each entity participating in a procurement program outlined in this subsection (c-10) must be done by equity eligible persons or equity eligible contractors. The Agency shall increase the minimum percentage each delivery year thereafter by increments that ensure a statewide average of 30% of the project workforce for each entity participating in a procurement program is done by equity eligible persons or equity eligible contractors by 2030. The Agency shall propose a schedule of percentage increases to the minimum equity standards in its draft revised renewable energy resources procurement plan submitted to the Commission for approval pursuant to paragraph (5) of subsection (b) of Section 16-111.5 of the Public Utilities Act. In determining these annual increases, the Agency shall have the discretion to establish different minimum equity standards for different types of procurements and different regions of the State if the Agency finds that doing so will further the purposes of this subsection (c-10). The proposed schedule of annual increases shall be revisited and updated on an annual basis. Revisions shall be developed with stakeholder input, including from equity eligible persons, equity eligible contractors, clean energy industry representatives, and community-based organizations that work with such persons and contractors.

(A) At the start of each delivery year, the Agency shall require a compliance plan from each entity participating in a procurement program of subsection (c) of this Section that demonstrates how they will achieve compliance with the minimum equity standard percentage for work completed in that delivery year. If an entity applies for its approved vendor or designee status between delivery years, the Agency shall require a compliance plan at the time of application.

(B) Halfway through each delivery year, the Agency shall require each entity participating in a procurement program to confirm that it will achieve compliance in that delivery year, when applicable. The Agency may offer corrective action plans to entities that are not on track to achieve compliance.

(C) At the end of each delivery year, each entity participating and completing work in that delivery year in a procurement program of subsection (c) shall submit a report to the Agency that demonstrates how it achieved compliance with the minimum equity standards percentage for that delivery year.

(D) The Agency shall prohibit participation in procurement programs by an approved vendor or designee, as applicable, or entities with which an approved vendor or designee, as applicable, shares a common parent company if an approved vendor or designee, as applicable, failed to meet the minimum equity standards for the prior delivery year. Waivers approved for lack of equity eligible persons or equity eligible contractors in a geographic area of a project shall not count against the approved vendor or designee. The Agency shall offer a corrective action plan for any such entities to assist them in obtaining compliance and shall allow continued access to procurement programs upon an approved vendor or designee demonstrating compliance.

(E) The Agency shall pursue efficiencies achieved by combining with other approved vendor or designee reporting.

(2) Equity accountability system within the Adjustable Block program. The equity category described in item (vi) of subparagraph (K) of subsection (c) is only available to applicants that are equity eligible contractors.

(3) Equity accountability system within competitive procurements. Through its long-term renewable resources procurement plan, the Agency shall develop requirements for ensuring that competitive procurement processes, including utility-scale solar, utility-scale wind, and brownfield site photovoltaic projects, advance the equity goals of this subsection (c-10). Subject to Commission approval, the Agency shall develop bid application requirements and a bid evaluation methodology for ensuring that utilization of equity eligible contractors, whether as bidders or as participants on project development, is optimized, including requiring that winning or successful applicants for utility-scale projects are or will partner with equity eligible contractors and giving preference to bids through which a higher portion of contract value flows to equity eligible contractors. To the extent practicable, entities participating in competitive procurements shall also be required to meet all the equity accountability requirements for approved vendors and their designees under this subsection (c-10). In developing these requirements, the Agency shall also consider whether equity goals can be further advanced through additional measures.

(4) In the first revision to the long-term renewable energy resources procurement plan and each revision thereafter, the Agency shall include the following:

(A) The current status and number of equity eligible contractors listed in the Energy Workforce Equity Database designed in subsection (c-25), including the number of equity eligible contractors with current certifications as issued by the Agency.

(B) A mechanism for measuring, tracking, and reporting project workforce at the approved vendor or designee level, as applicable, which shall include a measurement methodology and records to be made available for audit by the Agency or the Program Administrator.

(C) A program for approved vendors, designees, eligible persons, and equity eligible contractors to receive trainings, guidance, and other support from the Agency or its designee regarding the equity category outlined in item (vi) of subparagraph (K) of paragraph (1) of subsection (c) and in meeting the minimum equity standards of this subsection (c-10).

(D) A process for certifying equity eligible contractors and equity eligible persons. The certification process shall coordinate with the Energy Workforce Equity Database set forth in subsection (c-25).

(E) An application for waiver of the minimum equity standards of this subsection, which the Agency shall have the discretion to grant in rare circumstances. The Agency may grant such a waiver where the applicant provides evidence of significant efforts toward meeting the minimum equity commitment, including: use of the Energy Workforce Equity Database; efforts to hire or contract with entities that hire eligible persons; and efforts to establish contracting relationships with eligible contractors. The Agency shall support applicants in understanding the Energy Workforce Equity Database and other resources for pursuing compliance of the minimum equity standards. Waivers shall be project-specific, unless the Agency deems it necessary to grant a waiver across a portfolio of projects, and in effect for no longer than one year. Any waiver extension or subsequent waiver request from an applicant shall be subject to the requirements of this Section and shall specify efforts made to reach compliance. When considering whether to grant a waiver, and to what extent, the Agency shall consider the degree to which similarly situated applicants have been able to meet these minimum equity commitments. For repeated waiver requests for specific lack of eligible persons or eligible contractors available, the Agency shall make recommendations to target recruitment to add such eligible persons or eligible contractors to the database.

(5) The Agency shall collect information about work on projects or portfolios of projects subject to these minimum equity standards to ensure compliance with this subsection (c-10). Reporting in furtherance of this requirement may be combined with other annual reporting requirements. Such reporting shall include proof of certification of each equity eligible contractor or equity eligible person during the applicable time period.

(6) The Agency shall keep confidential all information and communication that provides private or personal information.

(7) Modifications to the equity accountability system. As part of the update of the long-term renewable resources procurement plan to be initiated in 2023, or sooner if the Agency deems necessary, the Agency shall determine the extent to which the equity accountability system described in this subsection (c-10) has advanced the goals of this amendatory Act of the 102nd General Assembly, including through the inclusion of equity eligible persons and equity eligible contractors in renewable energy credit projects. If the Agency finds that the equity accountability system has failed to meet those goals to its fullest potential, the Agency may revise the following criteria for future Agency procurements: (A) the percentage of project workforce, or other appropriate workforce measure, certified as equity eligible persons or equity eligible contractors; (B) definitions for equity investment eligible persons and equity investment eligible community; and (C) such other modifications necessary to advance the goals of this amendatory Act of the 102nd General Assembly effectively. Such revised criteria may also establish distinct equity accountability systems for different types of procurements or different regions of the State if the Agency finds that doing so will further the purposes of such programs. Revisions shall be developed with stakeholder input, including from equity eligible persons, equity eligible contractors, and community-based organizations that work with such persons and contractors.

(c-15) Racial discrimination elimination powers and process.

(1) Purpose. It is the purpose of this subsection to empower the Agency and other State actors to remedy racial discrimination in Illinois' clean energy economy as effectively and expediently as possible, including through the use of race-conscious remedies, such as race-conscious contracting and hiring goals, as consistent with State and federal law.

(2) Racial disparity and discrimination review process.

(A) Within one year after awarding contracts using the equity actions processes established in this Section, the Agency shall publish a report evaluating the effectiveness of the equity actions point criteria of this Section in increasing participation of equity eligible persons and equity eligible contractors. The report shall disaggregate participating workers and contractors by race and ethnicity. The report shall be forwarded to the Governor, the General Assembly, and the Illinois Commerce Commission and be made available to the public.

(B) As soon as is practicable thereafter, the Agency, in consultation with the Department of Commerce and Economic Opportunity, Department of Labor, and other agencies that may be relevant, shall commission and publish a disparity and availability study that measures the presence and impact of discrimination on minority businesses and workers in Illinois' clean energy economy. The Agency may hire consultants and experts to conduct the disparity and availability study, with the retention of those consultants and experts exempt from the requirements of Section 20-10 of the Illinois Procurement Code. The Illinois Power Agency shall forward a copy of its findings and recommendations to the Governor, the General Assembly, and the Illinois Commerce Commission. If the disparity and availability study establishes a strong basis in evidence that there is discrimination in Illinois' clean energy economy, the Agency, Department of Commerce and Economic Opportunity, Department of Labor, Department of Corrections, and other appropriate agencies shall take appropriate remedial actions, including race-conscious remedial actions as consistent with State and federal law, to effectively remedy this discrimination. Such remedies may include modification of the equity accountability system as described in subsection (c-10).

(c-20) Program data collection.

(1) Purpose. Data collection, data analysis, and reporting are critical to ensure that the benefits of the clean energy economy provided to Illinois residents and businesses are equitably distributed across the State. The Agency shall collect data from program applicants in order to track and improve equitable distribution of benefits across Illinois communities for all procurements the Agency conducts. The Agency shall use this data to, among other things, measure any potential impact of racial discrimination on the distribution of benefits and provide information necessary to correct any discrimination through methods consistent with State and federal law.

(2) Agency collection of program data. The Agency shall collect demographic and geographic data for each entity awarded contracts under any Agency-administered program.

(3) Required information to be collected. The Agency shall collect the following information from applicants and program participants where applicable:

(A) demographic information, including racial or ethnic identity for real persons employed, contracted, or subcontracted through the program and owners of businesses or entities that apply to receive renewable energy credits from the Agency;

(B) geographic location of the residency of real persons employed, contracted, or subcontracted through the program and geographic location of the headquarters of the business or entity that applies to receive renewable energy credits from the Agency; and

(C) any other information the Agency determines is necessary for the purpose of achieving the purpose of this subsection.

(4) Publication of collected information. The Agency shall publish, at least annually, information on the demographics of program participants on an aggregate basis.

(5) Nothing in this subsection shall be interpreted to limit the authority of the Agency, or other agency or department of the State, to require or collect demographic information from applicants of other State programs.

(c-25) Energy Workforce Equity Database.

(1) The Agency, in consultation with the Department of Commerce and Economic Opportunity, shall create an Energy Workforce Equity Database, and may contract with a third party to do so ("database program administrator"). If the Department decides to contract with a third party, that third party shall be exempt from the requirements of Section 20-10 of the Illinois Procurement Code. The Energy Workforce Equity Database shall be a searchable database of suppliers, vendors, and subcontractors for clean energy industries that is:

(A) publicly accessible;

(B) easy for people to find and use;

(C) organized by company specialty or field;

(D) region-specific; and

(E) populated with information including, but not limited to, contacts for suppliers, vendors, or subcontractors who are minority and women-owned business enterprise certified or who participate or have participated in any of the programs described in this Act.

(2) The Agency shall create an easily accessible, public facing online tool using the database information that includes, at a minimum, the following:

(A) a map of environmental justice and equity investment eligible communities;

(B) job postings and recruiting opportunities;

(C) a means by which recruiting clean energy companies can find and interact with current or former participants of clean energy workforce training programs;

(D) information on workforce training service providers and training opportunities available to prospective workers;

(E) renewable energy company diversity reporting;

(F) a list of equity eligible contractors with their contact information, types of work performed, and locations worked in;

(G) reporting on outcomes of the programs described in the workforce programs of the Energy Transition Act, including information such as, but not limited to, retention rate, graduation rate, and placement rates of trainees; and

(H) information about the Jobs and Environmental Justice Grant Program, the Clean Energy Jobs and Justice Fund, and other sources of capital.

(3) The Agency shall ensure the database is regularly updated to ensure information is current and shall coordinate with the Department of Commerce and Economic Opportunity to ensure that it includes information on individuals and entities that are or have participated in the Clean Jobs Workforce Network Program, Clean Energy Contractor Incubator Program, Returning Residents Clean Jobs Training Program, or Clean Energy Primes Contractor Accelerator Program.

(c-30) Enforcement of minimum equity standards. All entities seeking renewable energy credits must submit an annual report to demonstrate compliance with each of the equity commitments required under subsection (c-10). If the Agency concludes the entity has not met or maintained its minimum equity standards required under the applicable subparagraphs under subsection (c-10), the Agency shall deny the entity's ability to participate in procurement programs in subsection (c), including by withholding approved vendor or designee status. The Agency may require the entity to enter into a corrective action plan. An entity that is not recertified for failing to meet required equity actions in subparagraph (c-10) may reapply once they have a corrective action plan and achieve compliance with the minimum equity standards.

(d) Clean coal portfolio standard.

(1) The procurement plans shall include electricity generated using clean coal. Each utility shall enter into one or more sourcing agreements with the initial clean coal facility, as provided in paragraph (3) of this subsection (d), covering electricity generated by the initial clean coal facility representing at least 5% of each utility's total supply to serve the load of eligible retail customers in 2015 and each year thereafter, as described in paragraph (3) of this subsection (d), subject to the limits specified in paragraph (2) of this subsection (d). It is the goal of the State that by January 1, 2025, 25% of the electricity used in the State shall be generated by cost-effective clean coal facilities. For purposes of this subsection (d), "cost-effective" means that the expenditures pursuant to such sourcing agreements do not cause the limit stated in paragraph (2) of this subsection (d) to be exceeded and do not exceed cost-based benchmarks, which shall be developed to assess all expenditures pursuant to such sourcing agreements covering electricity generated by clean coal facilities, other than the initial clean coal facility, by the procurement administrator, in consultation with the Commission staff, Agency staff, and the procurement monitor and shall be subject to Commission review and approval.

A utility party to a sourcing agreement shall immediately retire any emission credits that it receives in connection with the electricity covered by such agreement.

Utilities shall maintain adequate records documenting the purchases under the sourcing agreement to comply with this subsection (d) and shall file an accounting with the load forecast that must be filed with the Agency by July 15 of each year, in accordance with subsection (d) of Section 16-111.5 of the Public Utilities Act.

A utility shall be deemed to have complied with the clean coal portfolio standard specified in this subsection (d) if the utility enters into a sourcing agreement as required by this subsection (d).

(2) For purposes of this subsection (d), the required execution of sourcing agreements with the initial clean coal facility for a particular year shall be measured as a percentage of the actual amount of electricity (megawatt-hours) supplied by the electric utility to eligible retail customers in the planning year ending immediately prior to the agreement's execution. For purposes of this subsection (d), the amount paid per kilowatthour means the total amount paid for electric service expressed on a per kilowatthour basis. For purposes of this subsection (d), the total amount paid for electric service includes without limitation amounts paid for supply, transmission, distribution, surcharges and add-on taxes.

Notwithstanding the requirements of this subsection (d), the total amount paid under sourcing agreements with clean coal facilities pursuant to the procurement plan for any given year shall be reduced by an amount necessary to limit the annual estimated average net increase due to the costs of these resources included in the amounts paid by eligible retail customers in connection with electric service to:

(A) in 2010, no more than 0.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009;

(B) in 2011, the greater of an additional 0.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2010 or 1% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009;

(C) in 2012, the greater of an additional 0.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2011 or 1.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009;

(D) in 2013, the greater of an additional 0.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2012 or 2% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009; and

(E) thereafter, the total amount paid under sourcing agreements with clean coal facilities pursuant to the procurement plan for any single year shall be reduced by an amount necessary to limit the estimated average net increase due to the cost of these resources included in the amounts paid by eligible retail customers in connection with electric service to no more than the greater of (i) 2.015% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009 or (ii) the incremental amount per kilowatthour paid for these resources in 2013. These requirements may be altered only as provided by statute.

No later than June 30, 2015, the Commission shall review the limitation on the total amount paid under sourcing agreements, if any, with clean coal facilities pursuant to this subsection (d) and report to the General Assembly its findings as to whether that limitation unduly constrains the amount of electricity generated by cost-effective clean coal facilities that is covered by sourcing agreements.

(3) Initial clean coal facility. In order to promote development of clean coal facilities in Illinois, each electric utility subject to this Section shall execute a sourcing agreement to source electricity from a proposed clean coal facility in Illinois (the "initial clean coal facility") that will have a nameplate capacity of at least 500 MW when commercial operation commences, that has a final Clean Air Act permit on June 1, 2009 (the effective date of Public Act 95-1027), and that will meet the definition of clean coal facility in Section 1-10 of this Act when commercial operation commences. The sourcing agreements with this initial clean coal facility shall be subject to both approval of the initial clean coal facility by the General Assembly and satisfaction of the requirements of paragraph (4) of this subsection (d) and shall be executed within 90 days after any such approval by the General Assembly. The Agency and the Commission shall have authority to inspect all books and records associated with the initial clean coal facility during the term of such a sourcing agreement. A utility's sourcing agreement for electricity produced by the initial clean coal facility shall include:

(A) a formula contractual price (the "contract price") approved pursuant to paragraph (4) of this subsection (d), which shall:

(i) be determined using a cost of service methodology employing either a level or deferred capital recovery component, based on a capital structure consisting of 45% equity and 55% debt, and a return on equity as may be approved by the Federal Energy Regulatory Commission, which in any case may not exceed the lower of 11.5% or the rate of return approved by the General Assembly pursuant to paragraph (4) of this subsection (d); and

(ii) provide that all miscellaneous net revenue, including but not limited to net revenue from the sale of emission allowances, if any, substitute natural gas, if any, grants or other support provided by the State of Illinois or the United States Government, firm transmission rights, if any, by-products produced by the facility, energy or capacity derived from the facility and not covered by a sourcing agreement pursuant to paragraph (3) of this subsection (d) or item (5) of subsection (d) of Section 16-115 of the Public Utilities Act, whether generated from the synthesis gas derived from coal, from SNG, or from natural gas, shall be credited against the revenue requirement for this initial clean coal facility;

(B) power purchase provisions, which shall:

(i) provide that the utility party to such sourcing agreement shall pay the contract price for electricity delivered under such sourcing agreement;

(ii) require delivery of electricity to the regional transmission organization market of the utility that is party to such sourcing agreement;

(iii) require the utility party to such sourcing agreement to buy from the initial clean coal facility in each hour an amount of energy equal to all clean coal energy made available from the initial clean coal facility during such hour times a fraction, the numerator of which is such utility's retail market sales of electricity (expressed in kilowatthours sold) in the State during the prior calendar month and the denominator of which is the total retail market sales of electricity (expressed in kilowatthours sold) in the State by utilities during such prior month and the sales of electricity (expressed in kilowatthours sold) in the State by alternative retail electric suppliers during such prior month that are subject to the requirements of this subsection (d) and paragraph (5) of subsection (d) of Section 16-115 of the Public Utilities Act, provided that the amount purchased by the utility in any year will be limited by paragraph (2) of this subsection (d); and

(iv) be considered pre-existing contracts in such utility's procurement plans for eligible retail customers;

(C) contract for differences provisions, which shall:

(i) require the utility party to such sourcing agreement to contract with the initial clean coal facility in each hour with respect to an amount of energy equal to all clean coal energy made available from the initial clean coal facility during such hour times a fraction, the numerator of which is such utility's retail market sales of electricity (expressed in kilowatthours sold) in the utility's service territory in the State during the prior calendar month and the denominator of which is the total retail market sales of electricity (expressed in kilowatthours sold) in the State by utilities during such prior month and the sales of electricity (expressed in kilowatthours sold) in the State by alternative retail electric suppliers during such prior month that are subject to the requirements of this subsection (d) and paragraph (5) of subsection (d) of Section 16-115 of the Public Utilities Act, provided that the amount paid by the utility in any year will be limited by paragraph (2) of this subsection (d);

(ii) provide that the utility's payment obligation in respect of the quantity of electricity determined pursuant to the preceding clause (i) shall be limited to an amount equal to (1) the difference between the contract price determined pursuant to subparagraph (A) of paragraph (3) of this subsection (d) and the day-ahead price for electricity delivered to the regional transmission organization market of the utility that is party to such sourcing agreement (or any successor delivery point at which such utility's supply obligations are financially settled on an hourly basis) (the "reference price") on the day preceding the day on which the electricity is delivered to the initial clean coal facility busbar, multiplied by (2) the quantity of electricity determined pursuant to the preceding clause (i); and

(iii) not require the utility to take physical delivery of the electricity produced by the facility;

(D) general provisions, which shall:

(i) specify a term of no more than 30 years, commencing on the commercial operation date of the facility;

(ii) provide that utilities shall maintain adequate records documenting purchases under the sourcing agreements entered into to comply with this subsection (d) and shall file an accounting with the load forecast that must be filed with the Agency by July 15 of each year, in accordance with subsection (d) of Section 16-111.5 of the Public Utilities Act;

(iii) provide that all costs associated with the initial clean coal facility will be periodically reported to the Federal Energy Regulatory Commission and to purchasers in accordance with applicable laws governing cost-based wholesale power contracts;

(iv) permit the Illinois Power Agency to assume ownership of the initial clean coal facility, without monetary consideration and otherwise on reasonable terms acceptable to the Agency, if the Agency so requests no less than 3 years prior to the end of the stated contract term;

(v) require the owner of the initial clean coal facility to provide documentation to the Commission each year, starting in the facility's first year of commercial operation, accurately reporting the quantity of carbon emissions from the facility that have been captured and sequestered and report any quantities of carbon released from the site or sites at which carbon emissions were sequestered in prior years, based on continuous monitoring of such sites. If, in any year after the first year of commercial operation, the owner of the facility fails to demonstrate that the initial clean coal facility captured and sequestered at least 50% of the total carbon emissions that the facility would otherwise emit or that sequestration of emissions from prior years has failed, resulting in the release of carbon dioxide into the atmosphere, the owner of the facility must offset excess emissions. Any such carbon offsets must be permanent, additional, verifiable, real, located within the State of Illinois, and legally and practicably enforceable. The cost of such offsets for the facility that are not recoverable shall not exceed $15 million in any given year. No costs of any such purchases of carbon offsets may be recovered from a utility or its customers. All carbon offsets purchased for this purpose and any carbon emission credits associated with sequestration of carbon from the facility must be permanently retired. The initial clean coal facility shall not forfeit its designation as a clean coal facility if the facility fails to fully comply with the applicable carbon sequestration requirements in any given year, provided the requisite offsets are purchased. However, the Attorney General, on behalf of the People of the State of Illinois, may specifically enforce the facility's sequestration requirement and the other terms of this contract provision. Compliance with the sequestration requirements and offset purchase requirements specified in paragraph (3) of this subsection (d) shall be reviewed annually by an independent expert retained by the owner of the initial clean coal facility, with the advance written approval of the Attorney General. The Commission may, in the course of the review specified in item (vii), reduce the allowable return on equity for the facility if the facility willfully fails to comply with the carbon capture and sequestration requirements set forth in this item (v);

(vi) include limits on, and accordingly provide for modification of, the amount the utility is required to source under the sourcing agreement consistent with paragraph (2) of this subsection (d);

(vii) require Commission review: (1) to determine the justness, reasonableness, and prudence of the inputs to the formula referenced in subparagraphs (A)(i) through (A)(iii) of paragraph (3) of this subsection (d), prior to an adjustment in those inputs including, without limitation, the capital structure and return on equity, fuel costs, and other operations and maintenance costs and (2) to approve the costs to be passed through to customers under the sourcing agreement by which the utility satisfies its statutory obligations. Commission review shall occur no less than every 3 years, regardless of whether any adjustments have been proposed, and shall be completed within 9 months;

(viii) limit the utility's obligation to such amount as the utility is allowed to recover through tariffs filed with the Commission, provided that neither the clean coal facility nor the utility waives any right to assert federal pre-emption or any other argument in response to a purported disallowance of recovery costs;

(ix) limit the utility's or alternative retail electric supplier's obligation to incur any liability until such time as the facility is in commercial operation and generating power and energy and such power and energy is being delivered to the facility busbar;

(x) provide that the owner or owners of the initial clean coal facility, which is the counterparty to such sourcing agreement, shall have the right from time to time to elect whether the obligations of the utility party thereto shall be governed by the power purchase provisions or the contract for differences provisions;

(xi) append documentation showing that the formula rate and contract, insofar as they relate to the power purchase provisions, have been approved by the Federal Energy Regulatory Commission pursuant to Section 205 of the Federal Power Act;

(xii) provide that any changes to the terms of the contract, insofar as such changes relate to the power purchase provisions, are subject to review under the public interest standard applied by the Federal Energy Regulatory Commission pursuant to Sections 205 and 206 of the Federal Power Act; and

(xiii) conform with customary lender requirements in power purchase agreements used as the basis for financing non-utility generators.

(4) Effective date of sourcing agreements with the initial clean coal facility. Any proposed sourcing agreement with the initial clean coal facility shall not become effective unless the following reports are prepared and submitted and authorizations and approvals obtained:

(i) Facility cost report. The owner of the initial clean coal facility shall submit to the Commission, the Agency, and the General Assembly a front-end engineering and design study, a facility cost report, method of financing (including but not limited to structure and associated costs), and an operating and maintenance cost quote for the facility (collectively "facility cost report"), which shall be prepared in accordance with the requirements of this paragraph (4) of subsection (d) of this Section, and shall provide the Commission and the Agency access to the work papers, relied upon documents, and any other backup documentation related to the facility cost report.

(ii) Commission report. Within 6 months following receipt of the facility cost report, the Commission, in consultation with the Agency, shall submit a report to the General Assembly setting forth its analysis of the facility cost report. Such report shall include, but not be limited to, a comparison of the costs associated with electricity generated by the initial clean coal facility to the costs associated with electricity generated by other types of generation facilities, an analysis of the rate impacts on residential and small business customers over the life of the sourcing agreements, and an analysis of the likelihood that the initial clean coal facility will commence commercial operation by and be delivering power to the facility's busbar by 2016. To assist in the preparation of its report, the Commission, in consultation with the Agency, may hire one or more experts or consultants, the costs of which shall be paid for by the owner of the initial clean coal facility. The Commission and Agency may begin the process of selecting such experts or consultants prior to receipt of the facility cost report.

(iii) General Assembly approval. The proposed sourcing agreements shall not take effect unless, based on the facility cost report and the Commission's report, the General Assembly enacts authorizing legislation approving (A) the projected price, stated in cents per kilowatthour, to be charged for electricity generated by the initial clean coal facility, (B) the projected impact on residential and small business customers' bills over the life of the sourcing agreements, and (C) the maximum allowable return on equity for the project; and

(iv) Commission review. If the General Assembly enacts authorizing legislation pursuant to subparagraph (iii) approving a sourcing agreement, the Commission shall, within 90 days of such enactment, complete a review of such sourcing agreement. During such time period, the Commission shall implement any directive of the General Assembly, resolve any disputes between the parties to the sourcing agreement concerning the terms of such agreement, approve the form of such agreement, and issue an order finding that the sourcing agreement is prudent and reasonable.

The facility cost report shall be prepared as follows:

(A) The facility cost report shall be prepared by duly licensed engineering and construction firms detailing the estimated capital costs payable to one or more contractors or suppliers for the engineering, procurement and construction of the components comprising the initial clean coal facility and the estimated costs of operation and maintenance of the facility. The facility cost report shall include:

(i) an estimate of the capital cost of the core plant based on one or more front end engineering and design studies for the gasification island and related facilities. The core plant shall include all civil, structural, mechanical, electrical, control, and safety systems.

(ii) an estimate of the capital cost of the balance of the plant, including any capital costs associated with sequestration of carbon dioxide emissions and all interconnects and interfaces required to operate the facility, such as transmission of electricity, construction or backfeed power supply, pipelines to transport substitute natural gas or carbon dioxide, potable water supply, natural gas supply, water supply, water discharge, landfill, access roads, and coal delivery.

The quoted construction costs shall be expressed in nominal dollars as of the date that the quote is prepared and shall include capitalized financing costs during construction, taxes, insurance, and other owner's costs, and an assumed escalation in materials and labor beyond the date as of which the construction cost quote is expressed.

(B) The front end engineering and design study for the gasification island and the cost study for the balance of plant shall include sufficient design work to permit quantification of major categories of materials, commodities and labor hours, and receipt of quotes from vendors of major equipment required to construct and operate the clean coal facility.

(C) The facility cost report shall also include an operating and maintenance cost quote that will provide the estimated cost of delivered fuel, personnel, maintenance contracts, chemicals, catalysts, consumables, spares, and other fixed and variable operations and maintenance costs. The delivered fuel cost estimate will be provided by a recognized third party expert or experts in the fuel and transportation industries. The balance of the operating and maintenance cost quote, excluding delivered fuel costs, will be developed based on the inputs provided by duly licensed engineering and construction firms performing the construction cost quote, potential vendors under long-term service agreements and plant operating agreements, or recognized third party plant operator or operators.

The operating and maintenance cost quote (including the cost of the front end engineering and design study) shall be expressed in nominal dollars as of the date that the quote is prepared and shall include taxes, insurance, and other owner's costs, and an assumed escalation in materials and labor beyond the date as of which the operating and maintenance cost quote is expressed.

(D) The facility cost report shall also include an analysis of the initial clean coal facility's ability to deliver power and energy into the applicable regional transmission organization markets and an analysis of the expected capacity factor for the initial clean coal facility.

(E) Amounts paid to third parties unrelated to the owner or owners of the initial clean coal facility to prepare the core plant construction cost quote, including the front end engineering and design study, and the operating and maintenance cost quote will be reimbursed through Coal Development Bonds.

(5) Re-powering and retrofitting coal-fired power plants previously owned by Illinois utilities to qualify as clean coal facilities. During the 2009 procurement planning process and thereafter, the Agency and the Commission shall consider sourcing agreements covering electricity generated by power plants that were previously owned by Illinois utilities and that have been or will be converted into clean coal facilities, as defined by Section 1-10 of this Act. Pursuant to such procurement planning process, the owners of such facilities may propose to the Agency sourcing agreements with utilities and alternative retail electric suppliers required to comply with subsection (d) of this Section and item (5) of subsection (d) of Section 16-115 of the Public Utilities Act, covering electricity generated by such facilities. In the case of sourcing agreements that are power purchase agreements, the contract price for electricity sales shall be established on a cost of service basis. In the case of sourcing agreements that are contracts for differences, the contract price from which the reference price is subtracted shall be established on a cost of service basis. The Agency and the Commission may approve any such utility sourcing agreements that do not exceed cost-based benchmarks developed by the procurement administrator, in consultation with the Commission staff, Agency staff and the procurement monitor, subject to Commission review and approval. The Commission shall have authority to inspect all books and records associated with these clean coal facilities during the term of any such contract.

(6) Costs incurred under this subsection (d) or pursuant to a contract entered into under this subsection (d) shall be deemed prudently incurred and reasonable in amount and the electric utility shall be entitled to full cost recovery pursuant to the tariffs filed with the Commission.

(d-5) Zero emission standard.

(1) Beginning with the delivery year commencing on June 1, 2017, the Agency shall, for electric utilities that serve at least 100,000 retail customers in this State, procure contracts with zero emission facilities that are reasonably capable of generating cost-effective zero emission credits in an amount approximately equal to 16% of the actual amount of electricity delivered by each electric utility to retail customers in the State during calendar year 2014. For an electric utility serving fewer than 100,000 retail customers in this State that requested, under Section 16-111.5 of the Public Utilities Act, that the Agency procure power and energy for all or a portion of the utility's Illinois load for the delivery year commencing June 1, 2016, the Agency shall procure contracts with zero emission facilities that are reasonably capable of generating cost-effective zero emission credits in an amount approximately equal to 16% of the portion of power and energy to be procured by the Agency for the utility. The duration of the contracts procured under this subsection (d-5) shall be for a term of 10 years ending May 31, 2027. The quantity of zero emission credits to be procured under the contracts shall be all of the zero emission credits generated by the zero emission facility in each delivery year; however, if the zero emission facility is owned by more than one entity, then the quantity of zero emission credits to be procured under the contracts shall be the amount of zero emission credits that are generated from the portion of the zero emission facility that is owned by the winning supplier.

The 16% value identified in this paragraph (1) is the average of the percentage targets in subparagraph (B) of paragraph (1) of subsection (c) of this Section for the 5 delivery years beginning June 1, 2017.

The procurement process shall be subject to the following provisions:

(A) Those zero emission facilities that intend to participate in the procurement shall submit to the Agency the following eligibility information for each zero emission facility on or before the date established by the Agency:

(i) the in-service date and remaining useful life of the zero emission facility;

(ii) the amount of power generated annually for each of the years 2005 through 2015, and the projected zero emission credits to be generated over the remaining useful life of the zero emission facility, which shall be used to determine the capability of each facility;

(iii) the annual zero emission facility cost projections, expressed on a per megawatthour basis, over the next 6 delivery years, which shall include the following: operation and maintenance expenses; fully allocated overhead costs, which shall be allocated using the methodology developed by the Institute for Nuclear Power Operations; fuel expenditures; non-fuel capital expenditures; spent fuel expenditures; a return on working capital; the cost of operational and market risks that could be avoided by ceasing operation; and any other costs necessary for continued operations, provided that "necessary" means, for purposes of this item (iii), that the costs could reasonably be avoided only by ceasing operations of the zero emission facility; and

(iv) a commitment to continue operating, for the duration of the contract or contracts executed under the procurement held under this subsection (d-5), the zero emission facility that produces the zero emission credits to be procured in the procurement.

The information described in item (iii) of this subparagraph (A) may be submitted on a confidential basis and shall be treated and maintained by the Agency, the procurement administrator, and the Commission as confidential and proprietary and exempt from disclosure under subparagraphs (a) and (g) of paragraph (1) of Section 7 of the Freedom of Information Act. The Office of Attorney General shall have access to, and maintain the confidentiality of, such information pursuant to Section 6.5 of the Attorney General Act.

(B) The price for each zero emission credit procured under this subsection (d-5) for each delivery year shall be in an amount that equals the Social Cost of Carbon, expressed on a price per megawatthour basis. However, to ensure that the procurement remains affordable to retail customers in this State if electricity prices increase, the price in an applicable delivery year shall be reduced below the Social Cost of Carbon by the amount ("Price Adjustment") by which the market price index for the applicable delivery year exceeds the baseline market price index for the consecutive 12-month period ending May 31, 2016. If the Price Adjustment is greater than or equal to the Social Cost of Carbon in an applicable delivery year, then no payments shall be due in that delivery year. The components of this calculation are defined as follows:

(i) Social Cost of Carbon: The Social Cost of Carbon is $16.50 per megawatthour, which is based on the U.S. Interagency Working Group on Social Cost of Carbon's price in the August 2016 Technical Update using a 3% discount rate, adjusted for inflation for each year of the program. Beginning with the delivery year commencing June 1, 2023, the price per megawatthour shall increase by $1 per megawatthour, and continue to increase by an additional $1 per megawatthour each delivery year thereafter.

(ii) Baseline market price index: The baseline market price index for the consecutive 12-month period ending May 31, 2016 is $31.40 per megawatthour, which is based on the sum of (aa) the average day-ahead energy price across all hours of such 12-month period at the PJM Interconnection LLC Northern Illinois Hub, (bb) 50% multiplied by the Base Residual Auction, or its successor, capacity price for the rest of the RTO zone group determined by PJM Interconnection LLC, divided by 24 hours per day, and (cc) 50% multiplied by the Planning Resource Auction, or its successor, capacity price for Zone 4 determined by the Midcontinent Independent System Operator, Inc., divided by 24 hours per day.

(iii) Market price index: The market price index for a delivery year shall be the sum of projected energy prices and projected capacity prices determined as follows:

(aa) Projected energy prices: the projected energy prices for the applicable delivery year shall be calculated once for the year using the forward market price for the PJM Interconnection, LLC Northern Illinois Hub. The forward market price shall be calculated as follows: the energy forward prices for each month of the applicable delivery year averaged for each trade date during the calendar year immediately preceding that delivery year to produce a single energy forward price for the delivery year. The forward market price calculation shall use data published by the Intercontinental Exchange, or its successor.

(bb) Projected capacity prices:

(I) For the delivery years commencing June 1, 2017, June 1, 2018, and June 1, 2019, the projected capacity price shall be equal to the sum of (1) 50% multiplied by the Base Residual Auction, or its successor, price for the rest of the RTO zone group as determined by PJM Interconnection LLC, divided by 24 hours per day and, (2) 50% multiplied by the resource auction price determined in the resource auction administered by the Midcontinent Independent System Operator, Inc., in which the largest percentage of load cleared for Local Resource Zone 4, divided by 24 hours per day, and where such price is determined by the Midcontinent Independent System Operator, Inc.

(II) For the delivery year commencing June 1, 2020, and each year thereafter, the projected capacity price shall be equal to the sum of (1) 50% multiplied by the Base Residual Auction, or its successor, price for the ComEd zone as determined by PJM Interconnection LLC, divided by 24 hours per day, and (2) 50% multiplied by the resource auction price determined in the resource auction administered by the Midcontinent Independent System Operator, Inc., in which the largest percentage of load cleared for Local Resource Zone 4, divided by 24 hours per day, and where such price is determined by the Midcontinent Independent System Operator, Inc.

For purposes of this subsection (d-5):

"Rest of the RTO" and "ComEd Zone" shall have the meaning ascribed to them by PJM Interconnection, LLC.

"RTO" means regional transmission organization.

(C) No later than 45 days after June 1, 2017 (the effective date of Public Act 99-906), the Agency shall publish its proposed zero emission standard procurement plan. The plan shall be consistent with the provisions of this paragraph (1) and shall provide that winning bids shall be selected based on public interest criteria that include, but are not limited to, minimizing carbon dioxide emissions that result from electricity consumed in Illinois and minimizing sulfur dioxide, nitrogen oxide, and particulate matter emissions that adversely affect the citizens of this State. In particular, the selection of winning bids shall take into account the incremental environmental benefits resulting from the procurement, such as any existing environmental benefits that are preserved by the procurements held under Public Act 99-906 and would cease to exist if the procurements were not held, including the preservation of zero emission facilities. The plan shall also describe in detail how each public interest factor shall be considered and weighted in the bid selection process to ensure that the public interest criteria are applied to the procurement and given full effect.

For purposes of developing the plan, the Agency shall consider any reports issued by a State agency, board, or commission under House Resolution 1146 of the 98th General Assembly and paragraph (4) of subsection (d) of this Section, as well as publicly available analyses and studies performed by or for regional transmission organizations that serve the State and their independent market monitors.

Upon publishing of the zero emission standard procurement plan, copies of the plan shall be posted and made publicly available on the Agency's website. All interested parties shall have 10 days following the date of posting to provide comment to the Agency on the plan. All comments shall be posted to the Agency's website. Following the end of the comment period, but no more than 60 days later than June 1, 2017 (the effective date of Public Act 99-906), the Agency shall revise the plan as necessary based on the comments received and file its zero emission standard procurement plan with the Commission.

If the Commission determines that the plan will result in the procurement of cost-effective zero emission credits, then the Commission shall, after notice and hearing, but no later than 45 days after the Agency filed the plan, approve the plan or approve with modification. For purposes of this subsection (d-5), "cost effective" means the projected costs of procuring zero emission credits from zero emission facilities do not cause the limit stated in paragraph (2) of this subsection to be exceeded.

(C-5) As part of the Commission's review and acceptance or rejection of the procurement results, the Commission shall, in its public notice of successful bidders:

(i) identify how the winning bids satisfy the public interest criteria described in subparagraph (C) of this paragraph (1) of minimizing carbon dioxide emissions that result from electricity consumed in Illinois and minimizing sulfur dioxide, nitrogen oxide, and particulate matter emissions that adversely affect the citizens of this State;

(ii) specifically address how the selection of winning bids takes into account the incremental environmental benefits resulting from the procurement, including any existing environmental benefits that are preserved by the procurements held under Public Act 99-906 and would have ceased to exist if the procurements had not been held, such as the preservation of zero emission facilities;

(iii) quantify the environmental benefit of preserving the resources identified in item (ii) of this subparagraph (C-5), including the following:

(aa) the value of avoided greenhouse gas emissions measured as the product of the zero emission facilities' output over the contract term multiplied by the U.S. Environmental Protection Agency eGrid subregion carbon dioxide emission rate and the U.S. Interagency Working Group on Social Cost of Carbon's price in the August 2016 Technical Update using a 3% discount rate, adjusted for inflation for each delivery year; and

(bb) the costs of replacement with other zero carbon dioxide resources, including wind and photovoltaic, based upon the simple average of the following:

(I) the price, or if there is more than one price, the average of the prices, paid for renewable energy credits from new utility-scale wind projects in the procurement events specified in item (i) of subparagraph (G) of paragraph (1) of subsection (c) of this Section; and

(II) the price, or if there is more than one price, the average of the prices, paid for renewable energy credits from new utility-scale solar projects and brownfield site photovoltaic projects in the procurement events specified in item (ii) of subparagraph (G) of paragraph (1) of subsection (c) of this Section and, after January 1, 2015, renewable energy credits from photovoltaic distributed generation projects in procurement events held under subsection (c) of this Section.

Each utility shall enter into binding contractual arrangements with the winning suppliers.

The procurement described in this subsection (d-5), including, but not limited to, the execution of all contracts procured, shall be completed no later than May 10, 2017. Based on the effective date of Public Act 99-906, the Agency and Commission may, as appropriate, modify the various dates and timelines under this subparagraph and subparagraphs (C) and (D) of this paragraph (1). The procurement and plan approval processes required by this subsection (d-5) shall be conducted in conjunction with the procurement and plan approval processes required by subsection (c) of this Section and Section 16-111.5 of the Public Utilities Act, to the extent practicable. Notwithstanding whether a procurement event is conducted under Section 16-111.5 of the Public Utilities Act, the Agency shall immediately initiate a procurement process on June 1, 2017 (the effective date of Public Act 99-906).

(D) Following the procurement event described in this paragraph (1) and consistent with subparagraph (B) of this paragraph (1), the Agency shall calculate the payments to be made under each contract for the next delivery year based on the market price index for that delivery year. The Agency shall publish the payment calculations no later than May 25, 2017 and every May 25 thereafter.

(E) Notwithstanding the requirements of this subsection (d-5), the contracts executed under this subsection (d-5) shall provide that the zero emission facility may, as applicable, suspend or terminate performance under the contracts in the following instances:

(i) A zero emission facility shall be excused from its performance under the contract for any cause beyond the control of the resource, including, but not restricted to, acts of God, flood, drought, earthquake, storm, fire, lightning, epidemic, war, riot, civil disturbance or disobedience, labor dispute, labor or material shortage, sabotage, acts of public enemy, explosions, orders, regulations or restrictions imposed by governmental, military, or lawfully established civilian authorities, which, in any of the foregoing cases, by exercise of commercially reasonable efforts the zero emission facility could not reasonably have been expected to avoid, and which, by the exercise of commercially reasonable efforts, it has been unable to overcome. In such event, the zero emission facility shall be excused from performance for the duration of the event, including, but not limited to, delivery of zero emission credits, and no payment shall be due to the zero emission facility during the duration of the event.

(ii) A zero emission facility shall be permitted to terminate the contract if legislation is enacted into law by the General Assembly that imposes or authorizes a new tax, special assessment, or fee on the generation of electricity, the ownership or leasehold of a generating unit, or the privilege or occupation of such generation, ownership, or leasehold of generation units by a zero emission facility. However, the provisions of this item (ii) do not apply to any generally applicable tax, special assessment or fee, or requirements imposed by federal law.

(iii) A zero emission facility shall be permitted to terminate the contract in the event that the resource requires capital expenditures in excess of $40,000,000 that were neither known nor reasonably foreseeable at the time it executed the contract and that a prudent owner or operator of such resource would not undertake.

(iv) A zero emission facility shall be permitted to terminate the contract in the event the Nuclear Regulatory Commission terminates the resource's license.

(F) If the zero emission facility elects to terminate a contract under subparagraph (E) of this paragraph (1), then the Commission shall reopen the docket in which the Commission approved the zero emission standard procurement plan under subparagraph (C) of this paragraph (1) and, after notice and hearing, enter an order acknowledging the contract termination election if such termination is consistent with the provisions of this subsection (d-5).

(2) For purposes of this subsection (d-5), the amount paid per kilowatthour means the total amount paid for electric service expressed on a per kilowatthour basis. For purposes of this subsection (d-5), the total amount paid for electric service includes, without limitation, amounts paid for supply, transmission, distribution, surcharges, and add-on taxes.

Notwithstanding the requirements of this subsection (d-5), the contracts executed under this subsection (d-5) shall provide that the total of zero emission credits procured under a procurement plan shall be subject to the limitations of this paragraph (2). For each delivery year, the contractual volume receiving payments in such year shall be reduced for all retail customers based on the amount necessary to limit the net increase that delivery year to the costs of those credits included in the amounts paid by eligible retail customers in connection with electric service to no more than 1.65% of the amount paid per kilowatthour by eligible retail customers during the year ending May 31, 2009. The result of this computation shall apply to and reduce the procurement for all retail customers, and all those customers shall pay the same single, uniform cents per kilowatthour charge under subsection (k) of Section 16-108 of the Public Utilities Act. To arrive at a maximum dollar amount of zero emission credits to be paid for the particular delivery year, the resulting per kilowatthour amount shall be applied to the actual amount of kilowatthours of electricity delivered by the electric utility in the delivery year immediately prior to the procurement, to all retail customers in its service territory. Unpaid contractual volume for any delivery year shall be paid in any subsequent delivery year in which such payments can be made without exceeding the amount specified in this paragraph (2). The calculations required by this paragraph (2) shall be made only once for each procurement plan year. Once the determination as to the amount of zero emission credits to be paid is made based on the calculations set forth in this paragraph (2), no subsequent rate impact determinations shall be made and no adjustments to those contract amounts shall be allowed. All costs incurred under those contracts and in implementing this subsection (d-5) shall be recovered by the electric utility as provided in this Section.

No later than June 30, 2019, the Commission shall review the limitation on the amount of zero emission credits procured under this subsection (d-5) and report to the General Assembly its findings as to whether that limitation unduly constrains the procurement of cost-effective zero emission credits.

(3) Six years after the execution of a contract under this subsection (d-5), the Agency shall determine whether the actual zero emission credit payments received by the supplier over the 6-year period exceed the Average ZEC Payment. In addition, at the end of the term of a contract executed under this subsection (d-5), or at the time, if any, a zero emission facility's contract is terminated under subparagraph (E) of paragraph (1) of this subsection (d-5), then the Agency shall determine whether the actual zero emission credit payments received by the supplier over the term of the contract exceed the Average ZEC Payment, after taking into account any amounts previously credited back to the utility under this paragraph (3). If the Agency determines that the actual zero emission credit payments received by the supplier over the relevant period exceed the Average ZEC Payment, then the supplier shall credit the difference back to the utility. The amount of the credit shall be remitted to the applicable electric utility no later than 120 days after the Agency's determination, which the utility shall reflect as a credit on its retail customer bills as soon as practicable; however, the credit remitted to the utility shall not exceed the total amount of payments received by the facility under its contract.

For purposes of this Section, the Average ZEC Payment shall be calculated by multiplying the quantity of zero emission credits delivered under the contract times the average contract price. The average contract price shall be determined by subtracting the amount calculated under subparagraph (B) of this paragraph (3) from the amount calculated under subparagraph (A) of this paragraph (3), as follows:

(A) The average of the Social Cost of Carbon, as defined in subparagraph (B) of paragraph (1) of this subsection (d-5), during the term of the contract.

(B) The average of the market price indices, as defined in subparagraph (B) of paragraph (1) of this subsection (d-5), during the term of the contract, minus the baseline market price index, as defined in subparagraph (B) of paragraph (1) of this subsection (d-5).

If the subtraction yields a negative number, then the Average ZEC Payment shall be zero.

(4) Cost-effective zero emission credits procured from zero emission facilities shall satisfy the applicable definitions set forth in Section 1-10 of this Act.

(5) The electric utility shall retire all zero emission credits used to comply with the requirements of this subsection (d-5).

(6) Electric utilities shall be entitled to recover all of the costs associated with the procurement of zero emission credits through an automatic adjustment clause tariff in accordance with subsection (k) and (m) of Section 16-108 of the Public Utilities Act, and the contracts executed under this subsection (d-5) shall provide that the utilities' payment obligations under such contracts shall be reduced if an adjustment is required under subsection (m) of Section 16-108 of the Public Utilities Act.

(7) This subsection (d-5) shall become inoperative on January 1, 2028.

(d-10) Nuclear Plant Assistance; carbon mitigation credits.

(1) The General Assembly finds:

(A) The health, welfare, and prosperity of all Illinois citizens require that the State of Illinois act to avoid and not increase carbon emissions from electric generation sources while continuing to ensure affordable, stable, and reliable electricity to all citizens.

(B) Absent immediate action by the State to preserve existing carbon-free energy resources, those resources may retire, and the electric generation needs of Illinois' retail customers may be met instead by facilities that emit significant amounts of carbon pollution and other harmful air pollutants at a high social and economic cost until Illinois is able to develop other forms of clean energy.

(C) The General Assembly finds that nuclear power generation is necessary for the State's transition to 100% clean energy, and ensuring continued operation of nuclear plants advances environmental and public health interests through providing carbon-free electricity while reducing the air pollution profile of the Illinois energy generation fleet.

(D) The clean energy attributes of nuclear generation facilities support the State in its efforts to achieve 100% clean energy.

(E) The State currently invests in various forms of clean energy, including, but not limited to, renewable energy, energy efficiency, and low-emission vehicles, among others.

(F) The Environmental Protection Agency commissioned an independent audit which provided a detailed assessment of the financial condition of the Illinois nuclear fleet to evaluate its financial viability and whether the environmental benefits of such resources were at risk. The report identified the risk of losing the environmental benefits of several specific nuclear units. The report also identified that the LaSalle County Generating Station will continue to operate through 2026 and therefore is not eligible to participate in the carbon mitigation credit program.

(G) Nuclear plants provide carbon-free energy, which helps to avoid many health-related negative impacts for Illinois residents.

(H) The procurement of carbon mitigation credits representing the environmental benefits of carbon-free generation will further the State's efforts at achieving 100% clean energy and decarbonizing the electricity sector in a safe, reliable, and affordable manner. Further, the procurement of carbon emission credits will enhance the health and welfare of Illinois residents through decreased reliance on more highly polluting generation.

(I) The General Assembly therefore finds it necessary to establish carbon mitigation credits to ensure decreased reliance on more carbon-intensive energy resources, for transitioning to a fully decarbonized electricity sector, and to help ensure health and welfare of the State's residents.

(2) As used in this subsection:

"Baseline costs" means costs used to establish a customer protection cap that have been evaluated through an independent audit of a carbon-free energy resource conducted by the Environmental Protection Agency that evaluated projected annual costs for operation and maintenance expenses; fully allocated overhead costs, which shall be allocated using the methodology developed by the Institute for Nuclear Power Operations; fuel expenditures; nonfuel capital expenditures; spent fuel expenditures; a return on working capital; the cost of operational and market risks that could be avoided by ceasing operation; and any other costs necessary for continued operations, provided that "necessary" means, for purposes of this definition, that the costs could reasonably be avoided only by ceasing operations of the carbon-free energy resource.

"Carbon mitigation credit" means a tradable credit that represents the carbon emission reduction attributes of one megawatt-hour of energy produced from a carbon-free energy resource.

"Carbon-free energy resource" means a generation facility that: (1) is fueled by nuclear power; and (2) is interconnected to PJM Interconnection, LLC.

(3) Procurement.

(A) Beginning with the delivery year commencing on June 1, 2022, the Agency shall, for electric utilities serving at least 3,000,000 retail customers in the State, seek to procure contracts for no more than approximately 54,500,000 cost-effective carbon mitigation credits from carbon-free energy resources because such credits are necessary to support current levels of carbon-free energy generation and ensure the State meets its carbon dioxide emissions reduction goals. The Agency shall not make a partial award of a contract for carbon mitigation credits covering a fractional amount of a carbon-free energy resource's projected output.

(B) Each carbon-free energy resource that intends to participate in a procurement shall be required to submit to the Agency the following information for the resource on or before the date established by the Agency:

(i) the in-service date and remaining useful life of the carbon-free energy resource;

(ii) the amount of power generated annually for each of the past 10 years, which shall be used to determine the capability of each facility;

(iii) a commitment to be reflected in any contract entered into pursuant to this subsection (d-10) to continue operating the carbon-free energy resource at a capacity factor of at least 88% annually on average for the duration of the contract or contracts executed under the procurement held under this subsection (d-10), except in an instance described in subparagraph (E) of paragraph (1) of subsection (d-5) of this Section or made impracticable as a result of compliance with law or regulation;

(iv) financial need and the risk of loss of the environmental benefits of such resource, which shall include the following information:

(I) the carbon-free energy resource's cost projections, expressed on a per megawatt-hour basis, over the next 5 delivery years, which shall include the following: operation and maintenance expenses; fully allocated overhead costs, which shall be allocated using the methodology developed by the Institute for Nuclear Power Operations; fuel expenditures; nonfuel capital expenditures; spent fuel expenditures; a return on working capital; the cost of operational and market risks that could be avoided by ceasing operation; and any other costs necessary for continued operations, provided that "necessary" means, for purposes of this subitem (I), that the costs could reasonably be avoided only by ceasing operations of the carbon-free energy resource; and

(II) the carbon-free energy resource's revenue projections, including energy, capacity, ancillary services, any other direct State support, known or anticipated federal attribute credits, known or anticipated tax credits, and any other direct federal support.

The information described in this subparagraph (B) may be submitted on a confidential basis and shall be treated and maintained by the Agency, the procurement administrator, and the Commission as confidential and proprietary and exempt from disclosure under subparagraphs (a) and (g) of paragraph (1) of Section 7 of the Freedom of Information Act. The Office of the Attorney General shall have access to, and maintain the confidentiality of, such information pursuant to Section 6.5 of the Attorney General Act.

(C) The Agency shall solicit bids for the contracts described in this subsection (d-10) from carbon-free energy resources that have satisfied the requirements of subparagraph (B) of this paragraph (3). The contracts procured pursuant to a procurement event shall reflect, and be subject to, the following terms, requirements, and limitations:

(i) Contracts are for delivery of carbon mitigation credits, and are not energy or capacity sales contracts requiring physical delivery. Pursuant to item (iii), contract payments shall fully deduct the value of any monetized federal production tax credits, credits issued pursuant to a federal clean energy standard, and other federal credits if applicable.

(ii) Contracts for carbon mitigation credits shall commence with the delivery year beginning on June 1, 2022 and shall be for a term of 5 delivery years concluding on May 31, 2027.

(iii) The price per carbon mitigation credit to be paid under a contract for a given delivery year shall be equal to an accepted bid price less the sum of:

(I) one of the following energy price indices, selected by the bidder at the time of the bid for the term of the contract:

(aa) the weighted-average hourly day-ahead price for the applicable delivery year at the busbar of all resources procured pursuant to this subsection (d-10), weighted by actual production from the resources; or

(bb) the projected energy price for the PJM Interconnection, LLC Northern Illinois Hub for the applicable delivery year determined according to subitem (aa) of item (iii) of subparagraph (B) of paragraph (1) of subsection (d-5).

(II) the Base Residual Auction Capacity Price for the ComEd zone as determined by PJM Interconnection, LLC, divided by 24 hours per day, for the applicable delivery year for the first 3 delivery years, and then any subsequent delivery years unless the PJM Interconnection, LLC applies the Minimum Offer Price Rule to participating carbon-free energy resources because they supply carbon mitigation credits pursuant to this Section at which time, upon notice by the carbon-free energy resource to the Commission and subject to the Commission's confirmation, the value under this subitem shall be zero, as further described in the carbon mitigation credit procurement plan; and

(III) any value of monetized federal tax credits, direct payments, or similar subsidy provided to the carbon-free energy resource from any unit of government that is not already reflected in energy prices.

If the price-per-megawatt-hour calculation performed under item (iii) of this subparagraph (C) for a given delivery year results in a net positive value, then the electric utility counterparty to the contract shall multiply such net value by the applicable contract quantity and remit the amount to the supplier.

To protect retail customers from retail rate impacts that may arise upon the initiation of carbon policy changes, if the price-per-megawatt-hour calculation performed under item (iii) of this subparagraph (C) for a given delivery year results in a net negative value, then the supplier counterparty to the contract shall multiply such net value by the applicable contract quantity and remit such amount to the electric utility counterparty. The electric utility shall reflect such amounts remitted by suppliers as a credit on its retail customer bills as soon as practicable.

(iv) To ensure that retail customers in Northern Illinois do not pay more for carbon mitigation credits than the value such credits provide, and notwithstanding the provisions of this subsection (d-10), the Agency shall not accept bids for contracts that exceed a customer protection cap equal to the baseline costs of carbon-free energy resources.

The baseline costs for the applicable year shall be the following:

(I) For the delivery year beginning June 1, 2022, the baseline costs shall be an amount equal to $30.30 per megawatt-hour.

(II) For the delivery year beginning June 1, 2023, the baseline costs shall be an amount equal to $32.50 per megawatt-hour.

(III) For the delivery year beginning June 1, 2024, the baseline costs shall be an amount equal to $33.43 per megawatt-hour.

(IV) For the delivery year beginning June 1, 2025, the baseline costs shall be an amount equal to $33.50 per megawatt-hour.

(V) For the delivery year beginning June 1, 2026, the baseline costs shall be an amount equal to $34.50 per megawatt-hour.

An Environmental Protection Agency consultant forecast, included in a report issued April 14, 2021, projects that a carbon-free energy resource has the opportunity to earn on average approximately $30.28 per megawatt-hour, for the sale of energy and capacity during the time period between 2022 and 2027. Therefore, the sale of carbon mitigation credits provides the opportunity to receive an additional amount per megawatt-hour in addition to the projected prices for energy and capacity.

Although actual energy and capacity prices may vary from year-to-year, the General Assembly finds that this customer protection cap will help ensure that the cost of carbon mitigation credits will be less than its value, based upon the social cost of carbon identified in the Technical Support Document issued in February 2021 by the U.S. Interagency Working Group on Social Cost of Greenhouse Gases and the PJM Interconnection, LLC carbon dioxide marginal emission rate for 2020, and that a carbon-free energy resource receiving payment for carbon mitigation credits receives no more than necessary to keep those units in operation.

(D) No later than 7 days after the effective date of this amendatory Act of the 102nd General Assembly, the Agency shall publish its proposed carbon mitigation credit procurement plan. The Plan shall provide that winning bids shall be selected by taking into consideration which resources best match public interest criteria that include, but are not limited to, minimizing carbon dioxide emissions that result from electricity consumed in Illinois and minimizing sulfur dioxide, nitrogen oxide, and particulate matter emissions that adversely affect the citizens of this State. The selection of winning bids shall also take into account the incremental environmental benefits resulting from the procurement or procurements, such as any existing environmental benefits that are preserved by a procurement held under this subsection (d-10) and would cease to exist if the procurement were not held, including the preservation of carbon-free energy resources. For those bidders having the same public interest criteria score, the relative ranking of such bidders shall be determined by price. The Plan shall describe in detail how each public interest factor shall be considered and weighted in the bid selection process to ensure that the public interest criteria are applied to the procurement. The Plan shall, to the extent practical and permissible by federal law, ensure that successful bidders make commercially reasonable efforts to apply for federal tax credits, direct payments, or similar subsidy programs that support carbon-free generation and for which the successful bidder is eligible. Upon publishing of the carbon mitigation credit procurement plan, copies of the plan shall be posted and made publicly available on the Agency's website. All interested parties shall have 7 days following the date of posting to provide comment to the Agency on the plan. All comments shall be posted to the Agency's website. Following the end of the comment period, but no more than 19 days later than the effective date of this amendatory Act of the 102nd General Assembly, the Agency shall revise the plan as necessary based on the comments received and file its carbon mitigation credit procurement plan with the Commission.

(E) If the Commission determines that the plan is likely to result in the procurement of cost-effective carbon mitigation credits, then the Commission shall, after notice and hearing and opportunity for comment, but no later than 42 days after the Agency filed the plan, approve the plan or approve it with modification. For purposes of this subsection (d-10), "cost-effective" means carbon mitigation credits that are procured from carbon-free energy resources at prices that are within the limits specified in this paragraph (3). As part of the Commission's review and acceptance or rejection of the procurement results, the Commission shall, in its public notice of successful bidders:

(i) identify how the selected carbon-free energy resources satisfy the public interest criteria described in this paragraph (3) of minimizing carbon dioxide emissions that result from electricity consumed in Illinois and minimizing sulfur dioxide, nitrogen oxide, and particulate matter emissions that adversely affect the citizens of this State;

(ii) specifically address how the selection of carbon-free energy resources takes into account the incremental environmental benefits resulting from the procurement, including any existing environmental benefits that are preserved by the procurements held under this amendatory Act of the 102nd General Assembly and would have ceased to exist if the procurements had not been held, such as the preservation of carbon-free energy resources;

(iii) quantify the environmental benefit of preserving the carbon-free energy resources procured pursuant to this subsection (d-10), including the following:

(I) an assessment value of avoided greenhouse gas emissions measured as the product of the carbon-free energy resources' output over the contract term, using generally accepted methodologies for the valuation of avoided emissions; and

(II) an assessment of costs of replacement with other carbon-free energy resources and renewable energy resources, including wind and photovoltaic generation, based upon an assessment of the prices paid for renewable energy credits through programs and procurements conducted pursuant to subsection (c) of Section 1-75 of this Act, and the additional storage necessary to produce the same or similar capability of matching customer usage patterns.

(F) The procurements described in this paragraph (3), including, but not limited to, the execution of all contracts procured, shall be completed no later than December 3, 2021. The procurement and plan approval processes required by this paragraph (3) shall be conducted in conjunction with the procurement and plan approval processes required by Section 16-111.5 of the Public Utilities Act, to the extent practicable. However, the Agency and Commission may, as appropriate, modify the various dates and timelines under this subparagraph and subparagraphs (D) and (E) of this paragraph (3) to meet the December 3, 2021 contract execution deadline. Following the completion of such procurements, and consistent with this paragraph (3), the Agency shall calculate the payments to be made under each contract in a timely fashion.

(F-1) Costs incurred by the electric utility pursuant to a contract authorized by this subsection (d-10) shall be deemed prudently incurred and reasonable in amount, and the electric utility shall be entitled to full cost recovery pursuant to a tariff or tariffs filed with the Commission.

(G) The counterparty electric utility shall retire all carbon mitigation credits used to comply with the requirements of this subsection (d-10).

(H) If a carbon-free energy resource is sold to another owner, the rights, obligations, and commitments under this subsection (d-10) shall continue to the subsequent owner.

(I) This subsection (d-10) shall become inoperative on January 1, 2028.

(e) The draft procurement plans are subject to public comment, as required by Section 16-111.5 of the Public Utilities Act.

(f) The Agency shall submit the final procurement plan to the Commission. The Agency shall revise a procurement plan if the Commission determines that it does not meet the standards set forth in Section 16-111.5 of the Public Utilities Act.

(g) The Agency shall assess fees to each affected utility to recover the costs incurred in preparation of the annual procurement plan for the utility.

(h) The Agency shall assess fees to each bidder to recover the costs incurred in connection with a competitive procurement process.

(i) A renewable energy credit, carbon emission credit, zero emission credit, or carbon mitigation credit can only be used once to comply with a single portfolio or other standard as set forth in subsection (c), subsection (d), or subsection (d-5) of this Section, respectively. A renewable energy credit, carbon emission credit, zero emission credit, or carbon mitigation credit cannot be used to satisfy the requirements of more than one standard. If more than one type of credit is issued for the same megawatt hour of energy, only one credit can be used to satisfy the requirements of a single standard. After such use, the credit must be retired together with any other credits issued for the same megawatt hour of energy.

(Source: P.A. 102-662, eff. 9-15-21; 103-380, eff. 1-1-24; 103-580, eff. 12-8-23.)

Section 65. The Public Utilities Act is amended by changing Sections 8-406, 8-406.1, 16-107.6, 16-108, 16-111.5, and 16-135 as follows:

(220 ILCS 5/8-406) (from Ch. 111 2/3, par. 8-406)

Sec. 8-406. Certificate of public convenience and necessity.

(a) No public utility not owning any city or village franchise nor engaged in performing any public service or in furnishing any product or commodity within this State as of July 1, 1921 and not possessing a certificate of public convenience and necessity from the Illinois Commerce Commission, the State Public Utilities Commission, or the Public Utilities Commission, at the time Public Act 84-617 goes into effect (January 1, 1986), shall transact any business in this State until it shall have obtained a certificate from the Commission that public convenience and necessity require the transaction of such business. A certificate of public convenience and necessity requiring the transaction of public utility business in any area of this State shall include authorization to the public utility receiving the certificate of public convenience and necessity to construct such plant, equipment, property, or facility as is provided for under the terms and conditions of its tariff and as is necessary to provide utility service and carry out the transaction of public utility business by the public utility in the designated area.

(b) No public utility shall begin the construction of any new plant, equipment, property, or facility which is not in substitution of any existing plant, equipment, property, or facility, or any extension or alteration thereof or in addition thereto, unless and until it shall have obtained from the Commission a certificate that public convenience and necessity require such construction. Whenever after a hearing the Commission determines that any new construction or the transaction of any business by a public utility will promote the public convenience and is necessary thereto, it shall have the power to issue certificates of public convenience and necessity. The Commission shall determine that proposed construction will promote the public convenience and necessity only if the utility demonstrates: (1) that the proposed construction is necessary to provide adequate, reliable, and efficient service to its customers and is the least-cost means of satisfying the service needs of its customers or that the proposed construction will promote the development of an effectively competitive electricity market that operates efficiently, is equitable to all customers, and is the least cost means of satisfying those objectives; (2) that the utility is capable of efficiently managing and supervising the construction process and has taken sufficient action to ensure adequate and efficient construction and supervision thereof; and (3) that the utility is capable of financing the proposed construction without significant adverse financial consequences for the utility or its customers.

(b-5) As used in this subsection (b-5):

"Qualifying direct current applicant" means an entity that seeks to provide direct current bulk transmission service for the purpose of transporting electric energy in interstate commerce.

"Qualifying direct current project" means a high voltage direct current electric service line that crosses at least one Illinois border, the Illinois portion of which is physically located within the region of the Midcontinent Independent System Operator, Inc., or its successor organization, and runs through the counties of Pike, Scott, Greene, Macoupin, Montgomery, Christian, Shelby, Cumberland, and Clark, is capable of transmitting electricity at voltages of 345 kilovolts or above, and may also include associated interconnected alternating current interconnection facilities in this State that are part of the proposed project and reasonably necessary to connect the project with other portions of the grid.

Notwithstanding any other provision of this Act, a qualifying direct current applicant that does not own, control, operate, or manage, within this State, any plant, equipment, or property used or to be used for the transmission of electricity at the time of its application or of the Commission's order may file an application on or before December 31, 2023 with the Commission pursuant to this Section or Section 8-406.1 for, and the Commission may grant, a certificate of public convenience and necessity to construct, operate, and maintain a qualifying direct current project. The qualifying direct current applicant may also include in the application requests for authority under Section 8-503. The Commission shall grant the application for a certificate of public convenience and necessity and requests for authority under Section 8-503 if it finds that the qualifying direct current applicant and the proposed qualifying direct current project satisfy the requirements of this subsection and otherwise satisfy the criteria of this Section or Section 8-406.1 and the criteria of Section 8-503, as applicable to the application and to the extent such criteria are not superseded by the provisions of this subsection. The Commission's order on the application for the certificate of public convenience and necessity shall also include the Commission's findings and determinations on the request or requests for authority pursuant to Section 8-503. Prior to filing its application under either this Section or Section 8-406.1, the qualifying direct current applicant shall conduct 3 public meetings in accordance with subsection (h) of this Section. If the qualifying direct current applicant demonstrates in its application that the proposed qualifying direct current project is designed to deliver electricity to a point or points on the electric transmission grid in either or both the PJM Interconnection, LLC or the Midcontinent Independent System Operator, Inc., or their respective successor organizations, the proposed qualifying direct current project shall be deemed to be, and the Commission shall find it to be, for public use. If the qualifying direct current applicant further demonstrates in its application that the proposed transmission project has a capacity of 1,000 megawatts or larger and a voltage level of 345 kilovolts or greater, the proposed transmission project shall be deemed to satisfy, and the Commission shall find that it satisfies, the criteria stated in item (1) of subsection (b) of this Section or in paragraph (1) of subsection (f) of Section 8-406.1, as applicable to the application, without the taking of additional evidence on these criteria. Prior to the transfer of functional control of any transmission assets to a regional transmission organization, a qualifying direct current applicant shall request Commission approval to join a regional transmission organization in an application filed pursuant to this subsection (b-5) or separately pursuant to Section 7-102 of this Act. The Commission may grant permission to a qualifying direct current applicant to join a regional transmission organization if it finds that the membership, and associated transfer of functional control of transmission assets, benefits Illinois customers in light of the attendant costs and is otherwise in the public interest. Nothing in this subsection (b-5) requires a qualifying direct current applicant to join a regional transmission organization. Nothing in this subsection (b-5) requires the owner or operator of a high voltage direct current transmission line that is not a qualifying direct current project to obtain a certificate of public convenience and necessity to the extent it is not otherwise required by this Section 8-406 or any other provision of this Act.

(c) As used in this subsection (c):

"Decommissioning" has the meaning given to that term in subsection (a) of Section 8-508.1.

"Nuclear power reactor" has the meaning given to that term in Section 8 of the Nuclear Safety Law of 2004.

After the effective date of this amendatory Act of the 103rd General Assembly, no construction shall commence on any new nuclear power reactor with a nameplate capacity of more than 300 megawatts of electricity to be located within this State, and no certificate of public convenience and necessity or other authorization shall be issued therefor by the Commission, until the Illinois Emergency Management Agency and Office of Homeland Security, in consultation with the Illinois Environmental Protection Agency and the Illinois Department of Natural Resources, finds that the United States Government, through its authorized agency, has identified and approved a demonstrable technology or means for the disposal of high level nuclear waste, or until such construction has been specifically approved by a statute enacted by the General Assembly. Beginning January 1, 2026, construction may commence on a new nuclear power reactor with a nameplate capacity of 300 megawatts of electricity or less within this State if the entity constructing the new nuclear power reactor has obtained all permits, licenses, permissions, or approvals governing the construction, operation, and funding of decommissioning of such nuclear power reactors required by: (1) this Act; (2) any rules adopted by the Illinois Emergency Management Agency and Office of Homeland Security under the authority of this Act; (3) any applicable federal statutes, including, but not limited to, the Atomic Energy Act of 1954, the Energy Reorganization Act of 1974, the Low-Level Radioactive Waste Policy Amendments Act of 1985, and the Energy Policy Act of 1992; (4) any regulations promulgated or enforced by the U.S. Nuclear Regulatory Commission, including, but not limited to, those codified at Title X, Parts 20, 30, 40, 50, 70, and 72 of the Code of Federal Regulations, as from time to time amended; and (5) any other federal or State statute, rule, or regulation governing the permitting, licensing, operation, or decommissioning of such nuclear power reactors. None of the rules developed by the Illinois Emergency Management Agency and Office of Homeland Security or any other State agency, board, or commission pursuant to this Act shall be construed to supersede the authority of the U.S. Nuclear Regulatory Commission. The changes made by this amendatory Act of the 103rd General Assembly shall not apply to the uprate, renewal, or subsequent renewal of any license for an existing nuclear power reactor that began operation prior to the effective date of this amendatory Act of the 103rd General Assembly.

None of the changes made in this amendatory Act of the 103rd General Assembly are intended to authorize the construction of nuclear power plants powered by nuclear power reactors that are not either: (1) small modular nuclear reactors; or (2) nuclear power reactors licensed by the U.S. Nuclear Regulatory Commission to operate in this State prior to the effective date of this amendatory Act of the 103rd General Assembly.

(d) In making its determination under subsection (b) of this Section, the Commission shall attach primary weight to the cost or cost savings to the customers of the utility. The Commission may consider any or all factors which will or may affect such cost or cost savings, including the public utility's engineering judgment regarding the materials used for construction.

(e) The Commission may issue a temporary certificate which shall remain in force not to exceed one year in cases of emergency, to assure maintenance of adequate service or to serve particular customers, without notice or hearing, pending the determination of an application for a certificate, and may by regulation exempt from the requirements of this Section temporary acts or operations for which the issuance of a certificate will not be required in the public interest.

A public utility shall not be required to obtain but may apply for and obtain a certificate of public convenience and necessity pursuant to this Section with respect to any matter as to which it has received the authorization or order of the Commission under the Electric Supplier Act, and any such authorization or order granted a public utility by the Commission under that Act shall as between public utilities be deemed to be, and shall have except as provided in that Act the same force and effect as, a certificate of public convenience and necessity issued pursuant to this Section.

No electric cooperative shall be made or shall become a party to or shall be entitled to be heard or to otherwise appear or participate in any proceeding initiated under this Section for authorization of power plant construction and as to matters as to which a remedy is available under the Electric Supplier Act.

(f) Such certificates may be altered or modified by the Commission, upon its own motion or upon application by the person or corporation affected. Unless exercised within a period of 2 years from the grant thereof, authority conferred by a certificate of convenience and necessity issued by the Commission shall be null and void.

No certificate of public convenience and necessity shall be construed as granting a monopoly or an exclusive privilege, immunity or franchise.

(g) A public utility that undertakes any of the actions described in items (1) through (3) of this subsection (g) or that has obtained approval pursuant to Section 8-406.1 of this Act shall not be required to comply with the requirements of this Section to the extent such requirements otherwise would apply. For purposes of this Section and Section 8-406.1 of this Act, "high voltage electric service line" means an electric line having a design voltage of 100,000 or more. For purposes of this subsection (g), a public utility may do any of the following:

(1) replace or upgrade any existing high voltage electric service line and related facilities, notwithstanding its length;

(2) relocate any existing high voltage electric service line and related facilities, notwithstanding its length, to accommodate construction or expansion of a roadway or other transportation infrastructure; or

(3) construct a high voltage electric service line and related facilities that is constructed solely to serve a single customer's premises or to provide a generator interconnection to the public utility's transmission system and that will pass under or over the premises owned by the customer or generator to be served or under or over premises for which the customer or generator has secured the necessary right of way.

(h) A public utility seeking to construct a high-voltage electric service line and related facilities (Project) must show that the utility has held a minimum of 2 pre-filing public meetings to receive public comment concerning the Project in each county where the Project is to be located, no earlier than 6 months prior to filing an application for a certificate of public convenience and necessity from the Commission. Notice of the public meeting shall be published in a newspaper of general circulation within the affected county once a week for 3 consecutive weeks, beginning no earlier than one month prior to the first public meeting. If the Project traverses 2 contiguous counties and where in one county the transmission line mileage and number of landowners over whose property the proposed route traverses is one-fifth or less of the transmission line mileage and number of such landowners of the other county, then the utility may combine the 2 pre-filing meetings in the county with the greater transmission line mileage and affected landowners. All other requirements regarding pre-filing meetings shall apply in both counties. Notice of the public meeting, including a description of the Project, must be provided in writing to the clerk of each county where the Project is to be located. A representative of the Commission shall be invited to each pre-filing public meeting.

(h-5) A public utility seeking to construct a high-voltage electric service line and related facilities must also show that the Project has complied with training and competence requirements under subsection (b) of Section 15 of the Electric Transmission Systems Construction Standards Act.

(i) For applications filed after August 18, 2015 (the effective date of Public Act 99-399), the Commission shall, by certified mail, notify each owner of record of land, as identified in the records of the relevant county tax assessor, included in the right-of-way over which the utility seeks in its application to construct a high-voltage electric line of the time and place scheduled for the initial hearing on the public utility's application. The utility shall reimburse the Commission for the cost of the postage and supplies incurred for mailing the notice.

(Source: P.A. 102-609, eff. 8-27-21; 102-662, eff. 9-15-21; 102-813, eff. 5-13-22; 102-931, eff. 5-27-22; 103-569, eff. 6-1-24.)

(220 ILCS 5/8-406.1)

Sec. 8-406.1. Certificate of public convenience and necessity; expedited procedure.

(a) A public utility may apply for a certificate of public convenience and necessity pursuant to this Section for the construction of any new high voltage electric service line and related facilities (Project). To facilitate the expedited review process of an application filed pursuant to this Section, an application shall include all of the following:

(1) Information in support of the application that shall include the following:

(A) A detailed description of the Project, including location maps and plot plans to scale showing all major components.

(B) The following engineering data:

(i) a detailed Project description including:

(I) name and destination of the Project;

(II) design voltage rating (kV);

(III) operating voltage rating (kV); and

(IV) normal peak operating current rating;

(ii) a conductor, structures, and substations description including:

(I) conductor size and type;

(II) type of structures;

(III) height of typical structures;

(IV) an explanation why these structures were selected;

(V) dimensional drawings of the typical structures to be used in the Project; and

(VI) a list of the names of all new (and existing if applicable) substations or switching stations that will be associated with the proposed new high voltage electric service line;

(iii) the location of the site and right-of-way including:

(I) miles of right-of-way;

(II) miles of circuit;

(III) width of the right-of-way; and

(IV) a brief description of the area traversed by the proposed high voltage electric service line, including a description of the general land uses in the area and the type of terrain crossed by the proposed line;

(iv) assumptions, bases, formulae, and methods used in the development and preparation of the diagrams and accompanying data, and a technical description providing the following information:

(I) number of circuits, with identification as to whether the circuit is overhead or underground;

(II) the operating voltage and frequency; and

(III) conductor size and type and number of conductors per phase;

(v) if the proposed interconnection is an overhead line, the following additional information also must be provided:

(I) the wind and ice loading design parameters;

(II) a full description and drawing of a typical supporting structure, including strength specifications;

(III) structure spacing with typical ruling and maximum spans;

(IV) conductor (phase) spacing; and

(V) the designed line-to-ground and conductor-side clearances;

(vi) if an underground or underwater interconnection is proposed, the following additional information also must be provided:

(I) burial depth;

(II) type of cable and a description of any required supporting equipment, such as insulation medium pressurizing or forced cooling;

(III) cathodic protection scheme; and

(IV) type of dielectric fluid and safeguards used to limit potential spills in waterways;

(vii) technical diagrams that provide clarification of any item under this item (1) should be included; and

(viii) applicant shall provide and identify a primary right-of-way and one or more alternate rights-of-way for the Project as part of the filing. To the extent applicable, for each right-of-way, an applicant shall provide the information described in this subsection (a). Upon a showing of good cause in its filing, an applicant may be excused from providing and identifying alternate rights-of-way.

(2) An application fee of $100,000, which shall be paid into the Public Utility Fund at the time the Chief Clerk of the Commission deems it complete and accepts the filing.

(3) Information showing that the utility has held a minimum of 3 pre-filing public meetings to receive public comment concerning the Project in each county where the Project is to be located, no earlier than 6 months prior to the filing of the application. Notice of the public meeting shall be published in a newspaper of general circulation within the affected county once a week for 3 consecutive weeks, beginning no earlier than one month prior to the first public meeting. If the Project traverses 2 contiguous counties and where in one county the transmission line mileage and number of landowners over whose property the proposed route traverses is 1/5 or less of the transmission line mileage and number of such landowners of the other county, then the utility may combine the 3 pre-filing meetings in the county with the greater transmission line mileage and affected landowners. All other requirements regarding pre-filing meetings shall apply in both counties. Notice of the public meeting, including a description of the Project, must be provided in writing to the clerk of each county where the Project is to be located. A representative of the Commission shall be invited to each pre-filing public meeting.

For applications filed after the effective date of this amendatory Act of the 99th General Assembly, the Commission shall, by certified mail, notify each owner of record of the land, as identified in the records of the relevant county tax assessor, included in the primary or alternate rights-of-way identified in the utility's application of the time and place scheduled for the initial hearing upon the public utility's application. The utility shall reimburse the Commission for the cost of the postage and supplies incurred for mailing the notice.

(b) At the first status hearing the administrative law judge shall set a schedule for discovery that shall take into consideration the expedited nature of the proceeding.

(c) Nothing in this Section prohibits a utility from requesting, or the Commission from approving, protection of confidential or proprietary information under applicable law. The public utility may seek confidential protection of any of the information provided pursuant to this Section, subject to Commission approval.

(d) The public utility shall publish notice of its application in the official State newspaper within 10 days following the date of the application's filing.

(e) The public utility shall establish a dedicated website for the Project 3 weeks prior to the first public meeting and maintain the website until construction of the Project is complete. The website address shall be included in all public notices.

(f) The Commission shall, after notice and hearing, grant a certificate of public convenience and necessity filed in accordance with the requirements of this Section if, based upon the application filed with the Commission and the evidentiary record, it finds the Project will promote the public convenience and necessity and that all of the following criteria are satisfied:

(1) That the Project is necessary to provide adequate, reliable, and efficient service to the public utility's customers and is the least-cost means of satisfying the service needs of the public utility's customers or that the Project will promote the development of an effectively competitive electricity market that operates efficiently, is equitable to all customers, and is the least cost means of satisfying those objectives.

(2) That the public utility is capable of efficiently managing and supervising the construction process and has taken sufficient action to ensure adequate and efficient construction and supervision of the construction.

(3) That the public utility is capable of financing the proposed construction without significant adverse financial consequences for the utility or its customers.

(4) That the Project has complied with training and competence and Diversity Plan requirements under subsections (b) and (d) of Section 15 of the Electric Transmission Systems Construction Standards Act.

(g) The Commission shall issue its decision with findings of fact and conclusions of law granting or denying the application no later than 150 days after the application is filed. The Commission may extend the 150-day deadline upon notice by an additional 75 days if, on or before the 30th day after the filing of the application, the Commission finds that good cause exists to extend the 150-day period.

(h) In the event the Commission grants a public utility's application for a certificate pursuant to this Section, the public utility shall pay a one-time construction fee to each county in which the Project is constructed within 30 days after the completion of construction. The construction fee shall be $20,000 per mile of high voltage electric service line constructed in that county, or a proportionate fraction of that fee. The fee shall be in lieu of any permitting fees that otherwise would be imposed by a county. Counties receiving a payment under this subsection (h) may distribute all or portions of the fee to local taxing districts in that county.

(i) Notwithstanding any other provisions of this Act, a decision granting a certificate under this Section shall include an order pursuant to Section 8-503 of this Act authorizing or directing the construction of the high voltage electric service line and related facilities as approved by the Commission, in the manner and within the time specified in said order.

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

(220 ILCS 5/16-107.6)

Sec. 16-107.6. Distributed generation rebate.

(a) In this Section:

"Additive services" means the services that distributed energy resources provide to the energy system and society that are not (1) already included in the base rebates for system-wide grid services; or (2) otherwise already compensated. Additive services may reflect, but shall not be limited to, any geographic, time-based, performance-based, and other benefits of distributed energy resources, as well as the present and future technological capabilities of distributed energy resources and present and future grid needs.

"Distributed energy resource" means a wide range of technologies that are located on the customer side of the customer's electric meter, including, but not limited to, distributed generation, energy storage, electric vehicles, and demand response technologies.

"Energy storage system" means commercially available technology that is capable of absorbing energy and storing it for a period of time for use at a later time, including, but not limited to, electrochemical, thermal, and electromechanical technologies, and may be interconnected behind the customer's meter or interconnected behind its own meter.

"Smart inverter" means a device that converts direct current into alternating current and meets the IEEE 1547-2018 equipment standards. Until devices that meet the IEEE 1547-2018 standard are available, devices that meet the UL 1741 SA standard are acceptable.

"Subscriber" has the meaning set forth in Section 1-10 of the Illinois Power Agency Act.

"Subscription" has the meaning set forth in Section 1-10 of the Illinois Power Agency Act.

"System-wide grid services" means the benefits that a distributed energy resource provides to the distribution grid for a period of no less than 25 years. System-wide grid services do not vary by location, time, or the performance characteristics of the distributed energy resource. System-wide grid services include, but are not limited to, avoided or deferred distribution capacity costs, resilience and reliability benefits, avoided or deferred distribution operation and maintenance costs, distribution voltage and power quality benefits, and line loss reductions.

"Threshold date" means December 31, 2024 or the date on which the utility's tariff or tariffs setting the new compensation values established under subsection (e) take effect, whichever is later.

(b) An electric utility that serves more than 200,000 customers in the State shall file a petition with the Commission requesting approval of the utility's tariff to provide a rebate to the owner or operator of distributed generation, including third-party owned systems, that meets the following criteria:

(1) has a nameplate generating capacity no greater than 5,000 kilowatts and is primarily used to offset a customer's electricity load;

(2) is located on the customer's side of the billing meter and for the customer's own use;

(3) is interconnected to electric distribution facilities owned by the electric utility under rules adopted by the Commission by means of one or more inverters the inverter or smart inverters inverter required by this Section, as applicable.

For purposes of this Section, "distributed generation" shall satisfy the definition of distributed renewable energy generation device set forth in Section 1-10 of the Illinois Power Agency Act to the extent such definition is consistent with the requirements of this Section.

In addition, any new photovoltaic distributed generation that is installed after June 1, 2017 (the effective date of Public Act 99-906) must be installed by a qualified person, as defined by subsection (i) of Section 1-56 of the Illinois Power Agency Act.

The tariff shall include a base rebate that compensates distributed generation for the system-wide grid services associated with distributed generation and, after the proceeding described in subsection (e) of this Section, an additional payment or payments for the additive services. The tariff shall provide that the smart inverter or smart inverters associated with the distributed generation shall provide autonomous response to grid conditions through its default settings as approved by the Commission. Default settings may not be changed after the execution of the interconnection agreement except by mutual agreement between the utility and the owner or operator of the distributed generation. Nothing in this Section shall negate or supersede Institute of Electrical and Electronics Engineers equipment standards or other similar standards or requirements. The tariff shall not limit the ability of the smart inverter or smart inverters or other distributed energy resource to provide wholesale market products such as regulation, demand response, or other services, or limit the ability of the owner of the smart inverter or the other distributed energy resource to receive compensation for providing those wholesale market products or services.

(b-5) Within 30 days after the effective date of this amendatory Act of the 102nd General Assembly, each electric public utility with 3,000,000 or more retail customers shall file a tariff with the Commission that further compensates any retail customer that installs or has installed photovoltaic facilities paired with energy storage facilities on or adjacent to its premises for the benefits the facilities provide to the distribution grid. The tariff shall provide that, in addition to the other rebates identified in this Section, the electric utility shall rebate to such retail customer (i) the previously incurred and future costs of installing interconnection facilities and related infrastructure to enable full participation in the PJM Interconnection, LLC or its successor organization frequency regulation market; and (ii) all wholesale demand charges incurred after the effective date of this amendatory Act of the 102nd General Assembly. The Commission shall approve, or approve with modification, the tariff within 120 days after the utility's filing.

(c) The proposed tariff authorized by subsection (b) of this Section shall include the following participation terms for rebates to be applied under this Section for distributed generation that satisfies the criteria set forth in subsection (b) of this Section:

(1) The owner or operator of distributed generation that services customers not eligible for net metering under subsection (d), (d-5), or (e) of Section 16-107.5 of this Act may apply for a rebate as provided for in this Section. Until the threshold date, the value of the rebate shall be $250 per kilowatt of nameplate generating capacity, measured as nominal DC power output, of that customer's distributed generation. To the extent the distributed generation also has an associated energy storage, then the energy storage system shall be separately compensated with a base rebate of $250 per kilowatt-hour of nameplate capacity. Any distributed generation device that is compensated for storage in this subsection (1) before the threshold date shall participate in one or more programs determined through the Multi-Year Integrated Grid Planning process that are designed to meet peak reduction and flexibility. After the threshold date, the value of the base rebate and additional compensation for any additive services shall be as determined by the Commission in the proceeding described in subsection (e) of this Section, provided that the value of the base rebate for system-wide grid services shall not be lower than $250 per kilowatt of nameplate generating capacity of distributed generation or community renewable generation project.

(2) The owner or operator of distributed generation that, before the threshold date, would have been eligible for net metering under subsection (d), (d-5), or (e) of Section 16-107.5 of this Act and that has not previously received a distributed generation rebate, may apply for a rebate as provided for in this Section. Until the threshold date, the value of the base rebate shall be $300 per kilowatt of nameplate generating capacity, measured as nominal DC power output, of the distributed generation. The owner or operator of distributed generation that, before the threshold date, is eligible for net metering under subsection (d), (d-5), or (e) of Section 16-107.5 of this Act may apply for a base rebate for an associated energy storage device behind the same retail customer meter that uses the same smart inverter as the distributed generation, regardless of whether the distributed generation applies for a rebate for the distributed generation device. The energy storage system shall be separately compensated at a base payment of $300 per kilowatt-hour of nameplate capacity. Any distributed generation device that is compensated for storage in this subsection (2) before the threshold date shall participate in a peak time rebate program, hourly pricing program, or time-of-use rate program offered by the applicable electric utility. After the threshold date, the value of the base rebate and additional compensation for any additive services shall be as determined by the Commission in the proceeding described in subsection (e) of this Section, provided that, prior to December 31, 2029, the value of the base rebate for system-wide services shall not be lower than $300 per kilowatt of nameplate generating capacity of distributed generation, after which it shall not be lower than $250 per kilowatt of nameplate capacity. The eligibility of energy storage devices that are interconnected behind the same retail customer meter as the distributed generation shall not be limited to energy storage devices interconnected after the effective date of this amendatory Act of the 103rd General Assembly. To the extent that an electric utility's tariffs are inconsistent with the requirements of this paragraph (2) as modified by this amendatory Act of the 103rd General Assembly, such electric utility shall, within 30 days, file modified tariffs consistent with the requirements of this paragraph (2).

(3) Upon approval of a rebate application submitted under this subsection (c), the retail customer shall no longer be entitled to receive any delivery service credits for the excess electricity generated by its facility and shall be subject to the provisions of subsection (n) of Section 16-107.5 of this Act unless the owner or operator receives a rebate only for an energy storage device and not for the distributed generation device.

(4) To be eligible for a rebate described in this subsection (c), the owner or operator of the distributed generation must have a smart inverter installed and in operation on the distributed generation.

(d) The Commission shall review the proposed tariff authorized by subsection (b) of this Section and may make changes to the tariff that are consistent with this Section and with the Commission's authority under Article IX of this Act, subject to notice and hearing. Following notice and hearing, the Commission shall issue an order approving, or approving with modification, such tariff no later than 240 days after the utility files its tariff. Upon the effective date of this amendatory Act of the 102nd General Assembly, an electric utility shall file a petition with the Commission to amend and update any existing tariffs to comply with subsections (b) and (c).

(e) By no later than June 30, 2023, the Commission shall open an independent, statewide investigation into the value of, and compensation for, distributed energy resources. The Commission shall conduct the investigation, but may arrange for experts or consultants independent of the utilities and selected by the Commission to assist with the investigation. The cost of the investigation shall be shared by the utilities filing tariffs under subsection (b) of this Section but may be recovered as an expense through normal ratemaking procedures.

(1) The Commission shall ensure that the investigation includes, at minimum, diverse sets of stakeholders; a review of best practices in calculating the value of distributed energy resource benefits; a review of the full value of the distributed energy resources and the manner in which each component of that value is or is not otherwise compensated; and assessments of how the value of distributed energy resources may evolve based on the present and future technological capabilities of distributed energy resources and based on present and future grid needs.

(2) The Commission's final order concluding this investigation shall establish an annual process and formula for the compensation of distributed generation and energy storage systems, and an initial set of inputs for that formula. The Commission's final order concluding this investigation shall establish base rebates that compensate distributed generation, community renewable generation projects and energy storage systems for the system-wide grid services that they provide. Those base rebate values shall be consistent across the state, and shall not vary by customer, customer class, customer location, or any other variable. With respect to rebates for distributed generation or community renewable generation projects, that rebate shall not be lower than $250 per kilowatt of nameplate generating capacity of the distributed generation or community renewable generation project. The Commission's final order concluding this proceeding shall also direct the utilities to update the formula, on an annual basis, with inputs derived from their integrated grid plans developed pursuant to Section 16-105.17. The base rebate shall be updated annually based on the annual updates to the formula inputs, but, with respect to rebates for distributed generation or community renewable generation projects, shall be no lower than $250 per kilowatt of nameplate generating capacity of the distributed generation or community renewable generation project.

(3) The Commission shall also determine, as a part of its investigation under this subsection, whether distributed energy resources can provide any additive services. Those additive services may include services that are provided through utility-controlled responses to grid conditions. If the Commission determines that distributed energy resources can provide additive grid services, the Commission shall determine the terms and conditions for the operation and compensation of those services. That compensation shall be above and beyond the base rebate that the distributed energy generation, community renewable generation project and energy storage system receives. Compensation for additive services may vary by location, time, performance characteristics, technology types, or other variables.

(4) The Commission shall ensure that compensation for distributed energy resources, including base rebates and any payments for additive services, shall reflect all reasonably known and measurable values of the distributed generation over its full expected useful life. Compensation for additive services shall reflect, but shall not be limited to, any geographic, time-based, performance-based, and other benefits of distributed generation, as well as the present and future technological capabilities of distributed energy resources and present and future grid needs.

(5) The Commission shall consider the electric utility's integrated grid plan developed pursuant to Section 16-105.17 of this Act to help identify the value of distributed energy resources for the purpose of calculating the compensation described in this subsection.

(6) The Commission shall determine additional compensation for distributed energy resources that creates savings and value on the distribution system by being co-located or in close proximity to electric vehicle charging infrastructure in use by medium-duty and heavy-duty vehicles, primarily serving environmental justice communities, as outlined in the utility integrated grid planning process under Section 16-105.17 of this Act.

No later than 60 days after the Commission enters its final order under this subsection (e), each utility shall file its updated tariff or tariffs in compliance with the order, including new tariffs for the recovery of costs incurred under this subsection (e) that shall provide for volumetric-based cost recovery, and the Commission shall approve, or approve with modification, the tariff or tariffs within 240 days after the utility's filing.

(f) Notwithstanding any provision of this Act to the contrary, the owner or operator of a community renewable generation project as defined in Section 1-10 of the Illinois Power Agency Act shall also be eligible to apply for the rebate described in this Section. The owner or operator of the community renewable generation project may apply for a rebate only if the owner or operator, or previous owner or operator, of the community renewable generation project has not already submitted an application, and, regardless of whether the subscriber is a residential or non-residential customer, may be allowed the amount identified in paragraph (1) of subsection (c) applicable on the date that the application is submitted.

(g) The owner of the distributed generation or community renewable generation project may apply for the rebate or rebates approved under this Section at the time of execution of an interconnection agreement with the distribution utility and shall receive the value available at that time of execution of the interconnection agreement, provided the project reaches mechanical completion within 24 months after execution of the interconnection agreement. If the project has not reached mechanical completion within 24 months after execution, the owner may reapply for the rebate or rebates approved under this Section available at the time of application and shall receive the value available at the time of application. The utility shall issue the rebate no later than 60 days after the project is energized. In the event the application is incomplete or the utility is otherwise unable to calculate the payment based on the information provided by the owner, the utility shall issue the payment no later than 60 days after the application is complete or all requested information is received.

(h) An electric utility shall recover from its retail customers all of the costs of the rebates made under a tariff or tariffs approved under subsection (d) of this Section, including, but not limited to, the value of the rebates and all costs incurred by the utility to comply with and implement subsections (b) and (c) of this Section, but not including costs incurred by the utility to comply with and implement subsection (e) of this Section, consistent with the following provisions:

(1) The utility shall defer the full amount of its costs as a regulatory asset. The total costs deferred as a regulatory asset shall be amortized over a 15-year period. The unamortized balance shall be recognized as of December 31 for a given year. The utility shall also earn a return on the total of the unamortized balance of the regulatory assets, less any deferred taxes related to the unamortized balance, at an annual rate equal to the utility's weighted average cost of capital that includes, based on a year-end capital structure, the utility's actual cost of debt for the applicable calendar year and a cost of equity, which shall be calculated as the sum of (i) the average for the applicable calendar year of the monthly average yields of 30-year U.S. Treasury bonds published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication; and (ii) 580 basis points, including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return.

When an electric utility creates a regulatory asset under the provisions of this paragraph (1) of subsection (h), the costs are recovered over a period during which customers also receive a benefit, which is in the public interest. Accordingly, it is the intent of the General Assembly that an electric utility that elects to create a regulatory asset under the provisions of this paragraph (1) shall recover all of the associated costs, including, but not limited to, its cost of capital as set forth in this paragraph (1). After the Commission has approved the prudence and reasonableness of the costs that comprise the regulatory asset, the electric utility shall be permitted to recover all such costs, and the value and recoverability through rates of the associated regulatory asset shall not be limited, altered, impaired, or reduced. To enable the financing of the incremental capital expenditures, including regulatory assets, for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State, the utility's actual year-end capital structure that includes a common equity ratio, excluding goodwill, of up to and including 50% of the total capital structure shall be deemed reasonable and used to set rates.

(2) The utility, at its election, may recover all of the costs as part of a filing for a general increase in rates under Article IX of this Act, as part of an annual filing to update a performance-based formula rate under subsection (d) of Section 16-108.5 of this Act, or through an automatic adjustment clause tariff, provided that nothing in this paragraph (2) permits the double recovery of such costs from customers. If the utility elects to recover the costs it incurs under subsections (b) and (c) through an automatic adjustment clause tariff, the utility may file its proposed tariff together with the tariff it files under subsection (b) of this Section or at a later time. The proposed tariff shall provide for an annual reconciliation, less any deferred taxes related to the reconciliation, with interest at an annual rate of return equal to the utility's weighted average cost of capital as calculated under paragraph (1) of this subsection (h), including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return, of the revenue requirement reflected in rates for each calendar year, beginning with the calendar year in which the utility files its automatic adjustment clause tariff under this subsection (h), with what the revenue requirement would have been had the actual cost information for the applicable calendar year been available at the filing date. The Commission shall review the proposed tariff and may make changes to the tariff that are consistent with this Section and with the Commission's authority under Article IX of this Act, subject to notice and hearing. Following notice and hearing, the Commission shall issue an order approving, or approving with modification, such tariff no later than 240 days after the utility files its tariff.

(i) An electric utility shall recover from its retail customers, on a volumetric basis, all of the costs of the rebates made under a tariff or tariffs placed into effect under subsection (e) of this Section, including, but not limited to, the value of the rebates and all costs incurred by the utility to comply with and implement subsection (e) of this Section, consistent with the following provisions:

(1) The utility may defer a portion of its costs as a regulatory asset. The Commission shall determine the portion that may be appropriately deferred as a regulatory asset. Factors that the Commission shall consider in determining the portion of costs that shall be deferred as a regulatory asset include, but are not limited to: (i) whether and the extent to which a cost effectively deferred or avoided other distribution system operating costs or capital expenditures; (ii) the extent to which a cost provides environmental benefits; (iii) the extent to which a cost improves system reliability or resilience; (iv) the electric utility's distribution system plan developed pursuant to Section 16-105.17 of this Act; (v) the extent to which a cost advances equity principles; and (vi) such other factors as the Commission deems appropriate. The remainder of costs shall be deemed an operating expense and shall be recoverable if found prudent and reasonable by the Commission.

The total costs deferred as a regulatory asset shall be amortized over a 15-year period. The unamortized balance shall be recognized as of December 31 for a given year. The utility shall also earn a return on the total of the unamortized balance of the regulatory assets, less any deferred taxes related to the unamortized balance, at an annual rate equal to the utility's weighted average cost of capital that includes, based on a year-end capital structure, the utility's actual cost of debt for the applicable calendar year and a cost of equity, which shall be calculated as the sum of: (I) the average for the applicable calendar year of the monthly average yields of 30-year U.S. Treasury bonds published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication; and (II) 580 basis points, including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return.

(2) The utility may recover all of the costs through an automatic adjustment clause tariff, on a volumetric basis. The utility may file its proposed cost-recovery tariff together with the tariff it files under subsection (e) of this Section or at a later time. The proposed tariff shall provide for an annual reconciliation, less any deferred taxes related to the reconciliation, with interest at an annual rate of return equal to the utility's weighted average cost of capital as calculated under paragraph (1) of this subsection (i), including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return, of the revenue requirement reflected in rates for each calendar year, beginning with the calendar year in which the utility files its automatic adjustment clause tariff under this subsection (i), with what the revenue requirement would have been had the actual cost information for the applicable calendar year been available at the filing date. The Commission shall review the proposed tariff and may make changes to the tariff that are consistent with this Section and with the Commission's authority under Article IX of this Act, subject to notice and hearing. Following notice and hearing, the Commission shall issue an order approving, or approving with modification, such tariff no later than 240 days after the utility files its tariff.

(j) No later than 90 days after the Commission enters an order, or order on rehearing, whichever is later, approving an electric utility's proposed tariff under this Section, the electric utility shall provide notice of the availability of rebates under this Section.

(Source: P.A. 102-662, eff. 9-15-21; 102-1031, eff. 5-27-22.)

(220 ILCS 5/16-135)

Sec. 16-135. Energy Storage Program.

(a) The Illinois General Assembly hereby finds and declares that:

(1) Energy storage systems provide opportunities to:

(A) reduce costs to ratepayers directly or indirectly by avoiding or deferring the need for investment in new generation and for upgrades to systems for the transmission and distribution of electricity;

(B) reduce the use of fossil fuels for meeting demand during peak load periods;

(C) provide ancillary services such as frequency response, load following, and voltage support;

(D) assist electric utilities with integrating sources of renewable energy into the grid for the transmission and distribution of electricity, and with maintaining grid stability;

(E) support diversification of energy resources;

(F) enhance the resilience and reliability of the electric grid; and

(G) reduce greenhouse gas emissions and other air pollutants resulting from power generation, thereby minimizing public health impacts that result from power generation.

(2) There are significant barriers to obtaining the benefits of energy storage systems, including inadequate valuation of the services that energy storage can provide to the grid and the public.

(3) It is in the public interest to:

(A) develop a robust competitive market for existing and new providers of energy storage systems in order to leverage Illinois' position as a leader in advanced energy and to capture the potential for economic development;

(B) implement targets and programs to achieve deployment of energy storage systems; and

(C) modernize distributed energy resource programs and interconnection standards to lower costs and efficiently deploy energy storage systems in order to increase economic development and job creation within the state's clean energy economy.

(b) In this Section:

"Energy storage peak standard" means a percentage of annual retail electricity sales during peak hours that an electric utility must derive from electricity discharged from eligible energy storage systems.

"Deployment" means the installation of energy storage systems through a variety of mechanisms, including utility procurement, customer installation, or other processes.

"Electric utility" has the same meaning as provided in Section 16-102 of this Act.

"Energy storage system" means a technology that is capable of absorbing zero-carbon energy, storing it for a period of time, and redelivering that energy after it has been stored in order to provide direct or indirect benefits to the broader electricity system. The term includes, but is not limited to, electrochemical, thermal, and electromechanical technologies.

"Nonwires alternatives solicitation" means a utility solicitation for third-party-owned or utility-owned distributed energy resources that uses nontraditional solutions to defer or replace planned investment on the distribution or transmission system.

"Total peak demand" means the highest hourly electricity demand for an electric utility in a given year, measured in megawatts, from all of the electric utility's customers of distribution service.

(c) The Commission, in consultation with the Illinois Power Agency, shall initiate a proceeding to examine specific programs, mechanisms, and policies that could support the deployment of energy storage systems. The Illinois Commerce Commission shall engage a broad group of Illinois stakeholders, including electric utilities, the energy storage industry, the renewable energy industry, and others to inform the proceeding. The proceeding must, at minimum:

(1) develop a framework to identify and measure the potential costs, benefits, that deployment of energy storage could produce, as well as barriers to realizing such benefits, including, but not limited to:

(A) avoided cost and deferred investments in generation, transmission, and distribution facilities;

(B) reduced ancillary services costs;

(C) reduced transmission and distribution congestion;

(D) lower peak power costs and reduced capacity costs;

(E) reduced costs for emergency power supplies during outages;

(F) reduced curtailment of renewable energy generators;

(G) reduced greenhouse gas emissions and other criteria air pollutants;

(H) increased grid hosting capacity of renewable energy generators that produce energy on an intermittent basis;

(I) increased reliability and resilience of the electric grid;

(J) reduced line losses;

(K) increased resource diversification;

(L) increased economic development;

(2) analyze and estimate:

(A) the impact on the system's ability to integrate renewable resources;

(B) the benefits of addition of storage at specific locations, such as at existing peaking units or locations on the grid close to large load centers;

(C) the impact on grid reliability and power quality; and

(D) the effect on retail electric rates and supply rates over the useful life of a given energy storage system; and

(3) evaluate and identify cost-effective policies and programs to support the deployment of energy storage systems, including, but not limited to:

(A) incentive programs;

(B) energy storage peak standards;

(C) nonwires alternative solicitation;

(D) peak demand reduction programs for behind-the-meter storage for all customer classes;

(E) value of distributed energy resources programs;

(F) tax incentives;

(G) time-varying rates;

(H) updating of interconnection processes and metering standards; and

(I) procurement by the Illinois Power Agency of energy storage resources.

(d) The Commission shall, no later than May 31, 2022, submit to the General Assembly and the Governor any recommendations for additional legislative, regulatory, or executive actions based on the findings of the proceeding.

(e) At the conclusion of the proceeding required under subsection (c), the Commission shall consider and recommend to the Governor and General Assembly energy storage deployment targets, if any, for each electric utility that serves more than 200,000 customers to be achieved by December 31, 2032, including recommended interim targets.

(f) In setting recommendations for energy storage deployment targets, the Commission shall:

(1) take into account the costs and benefits of procuring energy storage according to the framework developed in the proceeding under subsection (c);

(2) consider establishing specific subcategories of deployment of systems by point of interconnection or application.

(g) The Commission, in its role as the relevant electric retail regulatory authority for Illinois, shall initiate a workshop process no later than February 1, 2025, for the purpose of facilitating the development of an initial forward storage procurement process and model contract for the procurement of utility-scale energy storage resources, hereafter "initial procurement". The workshops shall be coordinated by the staff of the Commission, or a facilitator or any other experts or consultants retained by the staff of the Commission, in consultation with the Illinois Power Agency. The workshop process shall be designed to develop an effective initial procurement of no more than 1,500 megawatts of utility-scale stand-alone energy storage resources whereby the Illinois Power Agency shall be positioned to have developed a confidential benchmark and solicited, received, and opened sealed bids for such initial procurement to conclude not later than August 26, 2025. The workshop process shall conclude no later than April 1, 2025. Following the workshop process, the staff of the Commission, or the facilitator retained by the staff, shall prepare and submit a report to the Governor, the General Assembly, and the Commission no later than May 1, 2025, that summarizes the information obtained through the workshop process and recommends the most effective procurement process, structure, and contract terms that would result in a successful initial procurement.

Specifically, for the purposes of this initial procurement only, the report shall at a minimum include:

(1) a definition and key terms of contracting structures, including, but not limited to, tolling agreements and indexed credits, and whether they are used in other states;

(2) an assessment of changes to the contract structures, and the identification of appropriate signatories, used by other states necessary to fit the legal and regulatory structures of Illinois;

(3) commercial terms required for the contract to be financeable without creating contractual obligations on the utilities that are not contingent on full and timely cost recovery;

(4) contract structures that avoid a requirement that contracting utilities consider such agreement a lease under generally accepted accounting principles, or that such an agreement is reflected as debt on a contracting utility's balance sheet;

(5) necessary or appropriate roles for the owner of an energy storage system selected in a procurement to, either directly or through a third-party administrator which may be an affiliate, be responsible for operation, maintenance, dispatch, and other operational functions of the energy storage system;

(6) other allocations of rights and responsibilities between the winning bidder, the electric utility, and, if applicable, the third-party administrator;

(7) an assessment of whether a contract length different from 20 years is financeable, and whether other contract lengths would impact the net benefits of the storage procurement;

(8) a model of a standard contract, including contract terms and conditions, to be used by the Illinois Power Agency and its procurement administrator for the initial procurement;

(9) an analysis of whether 1,500 megawatts is the appropriate size for the initial procurement and whether additional procurements beyond August 2025 are valuable to Illinois taking into consideration the amount of projects in advanced stages of development and Illinois' need for storage energy systems in order to ensure it can meet its clean energy goals and to prevent or minimize any anticipated resource adequacy shortfalls;

(10) an assessment of the appropriate cost recovery and allocation structure that ensures electric utilities can recover all of the costs associated with the procurement of energy storage resources and any other costs associated with proposed utility participation;

(11) an assessment of the appropriate geographic location for the battery storage systems, including, but not limited to:

(A) the geographic split of the megawatts of capacity of the energy storage resources procured pursuant to this initial procurement between those interconnected to the Midcontinent ISO, Inc. and PJM Interconnection, LLC; and

(B) the potential benefits of procuring one or more projects within an area designated as an area of the State certified by the Department of Commerce and Economic Opportunity as an Enterprise zone or Energy Transition Grant Community;

(12) an assessment of minimum application requirements, such as having achieved interconnection milestones, including, but not limited to:

(A) projects that have applied for approval for surplus interconnection service or to transfer existing capacity interconnection rights to the relevant regional transmission organization and have received a completeness determination following completion of the initial review process and whether it is beneficial if such projects are also colocated with a renewable energy resource;

(B) for projects interconnected to MISO, projects that have signed an interconnection agreement, or are in the MISO Generating Facility Replacement Process, or have provided the most current deposit in the MISO definitive planning phase (DPP) cycle 2021 or an earlier definitive planning phase cycle; or

(C) for projects interconnected to PJM Interconnection, LLC, projects that have received a Phase 2 study;

(13) an assessment of the impact of the costs and benefits to Illinois ratepayers of these issues related to this initial procurement; and

(14) recommendations for the inclusion, or adaptation, of minimum equity standards and an equity accountability system to the procurement process.

Given the rapid actions required pursuant to this Section, the procurement of any facilitator, expert, or consultant pursuant to this subsection is exempt from the requirements of Section 20-10 of the Illinois Procurement Code.

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

Section 70. The Prevailing Wage Act is amended by changing Section 2 as follows:

(820 ILCS 130/2)

Sec. 2. This Act applies to the wages of laborers, mechanics and other workers employed in any public works, as hereinafter defined, by any public body and to anyone under contracts for public works. This includes any maintenance, repair, assembly, or disassembly work performed on equipment whether owned, leased, or rented.

As used in this Act, unless the context indicates otherwise:

"Public works" means all fixed works constructed or demolished by any public body, or paid for wholly or in part out of public funds. "Public works" as defined herein includes all projects financed in whole or in part with bonds, grants, loans, or other funds made available by or through the State or any of its political subdivisions, including but not limited to: bonds issued under the Industrial Project Revenue Bond Act (Article 11, Division 74 of the Illinois Municipal Code), the Industrial Building Revenue Bond Act, the Illinois Finance Authority Act, the Illinois Sports Facilities Authority Act, or the Build Illinois Bond Act; loans or other funds made available pursuant to the Build Illinois Act; loans or other funds made available pursuant to the Riverfront Development Fund under Section 10-15 of the River Edge Redevelopment Zone Act; or funds from the Fund for Illinois' Future under Section 6z-47 of the State Finance Act, funds for school construction under Section 5 of the General Obligation Bond Act, funds authorized under Section 3 of the School Construction Bond Act, funds for school infrastructure under Section 6z-45 of the State Finance Act, and funds for transportation purposes under Section 4 of the General Obligation Bond Act. "Public works" also includes (i) all projects financed in whole or in part with funds from the Environmental Protection Agency under the Illinois Renewable Fuels Development Program Act for which there is no project labor agreement; (ii) all work performed pursuant to a public private agreement under the Public Private Agreements for the Illiana Expressway Act or the Public-Private Agreements for the South Suburban Airport Act; (iii) all projects undertaken under a public-private agreement under the Public-Private Partnerships for Transportation Act or the Department of Natural Resources World Shooting and Recreational Complex Act; and (iv) all transportation facilities undertaken under a design-build contract or a Construction Manager/General Contractor contract under the Innovations for Transportation Infrastructure Act. "Public works" also includes all projects at leased facility property used for airport purposes under Section 35 of the Local Government Facility Lease Act. "Public works" also includes the construction of a new wind power facility by a business designated as a High Impact Business under Section 5.5(a)(3)(E) of the Illinois Enterprise Zone Act, and the construction of a new utility-scale solar power facility by a business designated as a High Impact Business under Section 5.5(a)(3)(E-5) of the Illinois Enterprise Zone Act, the construction of a new battery energy storage solution facility by a business designated as a High Impact Business under Section 5.5(a)(3)(I) of the Illinois Enterprise Zone Act, and the construction of a high voltage direct current converter station by a business designated as a High Impact Business under Section 5.5(a)(3)(J) of the Illinois Enterprise Zone Act. "Public works" also includes electric vehicle charging station projects financed pursuant to the Electric Vehicle Act and renewable energy projects required to pay the prevailing wage pursuant to the Illinois Power Agency Act. "Public works" also includes power washing projects by a public body or paid for wholly or in part out of public funds in which steam or pressurized water, with or without added abrasives or chemicals, is used to remove paint or other coatings, oils or grease, corrosion, or debris from a surface or to prepare a surface for a coating. "Public works" also includes all electric transmission systems projects subject to the Electric Transmission Systems Construction Standards Act. "Public works" does not include work done directly by any public utility company, whether or not done under public supervision or direction, or paid for wholly or in part out of public funds. "Public works" also includes construction projects performed by a third party contracted by any public utility, as described in subsection (a) of Section 2.1, in public rights-of-way, as defined in Section 21-201 of the Public Utilities Act, whether or not done under public supervision or direction, or paid for wholly or in part out of public funds. "Public works" also includes construction projects that exceed 15 aggregate miles of new fiber optic cable, performed by a third party contracted by any public utility, as described in subsection (b) of Section 2.1, in public rights-of-way, as defined in Section 21-201 of the Public Utilities Act, whether or not done under public supervision or direction, or paid for wholly or in part out of public funds. "Public works" also includes any corrective action performed pursuant to Title XVI of the Environmental Protection Act for which payment from the Underground Storage Tank Fund is requested. "Public works" also includes all construction projects involving fixtures or permanent attachments affixed to light poles that are owned by a public body, including street light poles, traffic light poles, and other lighting fixtures, whether or not done under public supervision or direction, or paid for wholly or in part out of public funds, unless the project is performed by employees employed directly by the public body. "Public works" also includes work performed subject to the Mechanical Insulation Energy and Safety Assessment Act. "Public works" also includes the removal, hauling, and transportation of biosolids, lime sludge, and lime residue from a water treatment plant or facility and the disposal of biosolids, lime sludge, and lime residue removed from a water treatment plant or facility at a landfill. "Public works" does not include projects undertaken by the owner at an owner-occupied single-family residence or at an owner-occupied unit of a multi-family residence. "Public works" does not include work performed for soil and water conservation purposes on agricultural lands, whether or not done under public supervision or paid for wholly or in part out of public funds, done directly by an owner or person who has legal control of those lands.

"Construction" means all work on public works involving laborers, workers or mechanics. This includes any maintenance, repair, assembly, or disassembly work performed on equipment whether owned, leased, or rented.

"Locality" means the county where the physical work upon public works is performed, except (1) that if there is not available in the county a sufficient number of competent skilled laborers, workers and mechanics to construct the public works efficiently and properly, "locality" includes any other county nearest the one in which the work or construction is to be performed and from which such persons may be obtained in sufficient numbers to perform the work and (2) that, with respect to contracts for highway work with the Department of Transportation of this State, "locality" may at the discretion of the Secretary of the Department of Transportation be construed to include two or more adjacent counties from which workers may be accessible for work on such construction.

"Public body" means the State or any officer, board or commission of the State or any political subdivision or department thereof, or any institution supported in whole or in part by public funds, and includes every county, city, town, village, township, school district, irrigation, utility, reclamation improvement or other district and every other political subdivision, district or municipality of the state whether such political subdivision, municipality or district operates under a special charter or not.

"Labor organization" means an organization that is the exclusive representative of an employer's employees recognized or certified pursuant to the National Labor Relations Act.

The terms "general prevailing rate of hourly wages", "general prevailing rate of wages" or "prevailing rate of wages" when used in this Act mean the hourly cash wages plus annualized fringe benefits for training and apprenticeship programs approved by the U.S. Department of Labor, Bureau of Apprenticeship and Training, health and welfare, insurance, vacations and pensions paid generally, in the locality in which the work is being performed, to employees engaged in work of a similar character on public works.

(Source: P.A. 102-9, eff. 1-1-22; 102-444, eff. 8-20-21; 102-673, eff. 11-30-21; 102-813, eff. 5-13-22; 102-1094, eff. 6-15-22; 103-8, eff. 6-7-23; 103-327, eff. 1-1-24; 103-346, eff. 1-1-24; 103-359, eff. 7-28-23; 103-447, eff. 8-4-23; 103-605, eff. 7-1-24.)

Section 99. Effective date. This Act takes effect upon becoming law.