2023 Illinois Compiled Statutes › Chapter 220 - UTILITIES › 220 ILCS 5/ - Public Utilities Act. › Article VIII - Service Obligations And Conditions

(220 ILCS 5/Art. VIII heading)
ARTICLE VIII.  
		SERVICE OBLIGATIONS AND CONDITIONS
(220 ILCS 5/8-101) (from Ch. 111 2/3, par. 8-101)
Sec. 8-101. 
		Duties of public utilities; nondiscrimination. 
		A
public utility shall furnish, provide, and maintain such
service instrumentalities, equipment, and facilities as shall promote the
safety, health, comfort, and convenience of its patrons, employees, and
public and as shall be in all respects adequate, efficient, just, and
reasonable.
All rules and regulations made by a public utility affecting or
pertaining to its charges or service to the public shall be just and
reasonable.
A public utility shall, upon reasonable notice, furnish to all
persons who may apply therefor and be reasonably entitled thereto, suitable
facilities and service, without discrimination and without delay.
Nothing in this Section shall be construed to prevent a public utility from
accepting payment electronically or by the use of a customer-preferred
financially accredited credit or debit methodology.
(Source: P.A. 92-22, eff. 6-30-01.)
(220 ILCS 5/8-101.5)
Sec. 8-101.5. Use of credit information of prospective and existing customers. A public utility may not deny, cancel, or nonrenew utility service  solely on
the basis of credit information of prospective or existing customers. If a public utility denies, cancels, or does not renew service based on credit information, it must provide the affected party with an explanation for the public utility's action and an opportunity for the affected party to explain its credit information. This Section does not apply to a telecommunications carrier or any of its affiliates.
(Source: P.A. 96-560, eff. 8-18-09.)
(220 ILCS 5/8-102) (from Ch. 111 2/3, par. 8-102)
Sec. 8-102. 
		Audit or investigation. 
		The Commission is authorized to
conduct or order a management audit or investigation of any public utility or
part thereof.  The audit or investigation may examine the
reasonableness, prudence, or efficiency of any aspect of the
utility's operations, costs, management, decisions or functions that may affect the adequacy, safety, efficiency or reliability of utility
service or the reasonableness or prudence of the costs
underlying rates or charges for utility service.  The Commission may conduct or
order a management audit or investigation only when it has reasonable grounds
to believe that the audit or investigation is necessary to assure
that the utility is providing adequate, efficient, reliable, safe,
and least-cost service and charging only just and reasonable rates
therefor, or that the audit or investigation is likely to be
cost-beneficial in enhancing the quality of service or the
reasonableness of rates therefor.  The Commission shall, before initiating
any such audit or investigation, issue an order describing the grounds for
the audit or investigation and the appropriate scope and nature of
the audit or investigation.  The scope and nature of any such
audit or investigation shall be reasonably related to the grounds relied upon
by the Commission in its order.
Any audit or investigation authorized pursuant to this Section may be
conducted by the Commission, or if the Commission is unable to adequately
perform the audit or investigation, the Commission may arrange for
it to be conducted by persons independent of the utility and selected by the
Commission.  The cost of an independent audit shall be borne initially
by the utility, but shall be recovered as an expense through normal
ratemaking procedures.  Any audit or investigation shall be conducted in
accordance with generally accepted auditing standards.
(Source: P.A. 90-655, eff. 7-30-98.)
(220 ILCS 5/8-103)
Sec. 8-103. Energy efficiency and demand-response measures.
(a) It is the policy of the State that electric utilities are required to use cost-effective energy efficiency and demand-response measures to reduce delivery load. Requiring investment in cost-effective energy efficiency and demand-response measures will  reduce direct and indirect costs to consumers by decreasing environmental impacts and by avoiding or delaying the need for new generation, transmission, and distribution infrastructure. It serves the public interest to allow electric utilities to recover costs for reasonably and prudently incurred expenses for energy efficiency and demand-response measures. As used in this Section, "cost-effective" means that the measures satisfy the total resource cost test. The low-income measures described in subsection (f)(4) of this Section shall not be required to meet the total resource cost test. For purposes of this Section, the terms "energy-efficiency", "demand-response", "electric utility", and "total resource cost test" shall have the meanings set forth in the Illinois Power Agency Act. For purposes of this Section, the amount per kilowatthour means the total amount paid for electric service expressed on a per kilowatthour basis. For purposes of this Section, the total amount paid for electric service includes without limitation estimated amounts paid for supply, transmission, distribution, surcharges, and add-on-taxes.
(a-5) This Section applies to electric utilities serving 500,000 or less but more than 200,000 retail customers in this State. Through December 31, 2017, this Section also applies to electric utilities serving more than 500,000 retail customers in the State.
(b) Electric utilities shall implement cost-effective energy efficiency measures to meet the following incremental annual energy savings goals:
(1) 0.2% of energy delivered in the year commencing     June 1, 2008;
(2) 0.4% of energy delivered in the year commencing     June 1, 2009;
(3) 0.6% of energy delivered in the year commencing     June 1, 2010;
(4) 0.8% of energy delivered in the year commencing     June 1, 2011;
(5) 1% of energy delivered in the year commencing     June 1, 2012;
(6) 1.4% of energy delivered in the year commencing     June 1, 2013;
(7) 1.8% of energy delivered in the year commencing     June 1, 2014; and
(8) 2% of energy delivered in the year commencing     June 1, 2015 and each year thereafter.
Electric utilities may comply with this subsection (b) by meeting the annual incremental savings goal in the applicable year or by showing that the total cumulative annual savings within a 3-year planning period associated with measures implemented after May 31, 2014 was equal to the sum of each annual incremental savings requirement from May 31, 2014 through the end of the applicable year.
(c) Electric utilities shall implement cost-effective demand-response measures to reduce peak demand by 0.1% over the prior year for eligible retail customers, as defined in Section 16-111.5 of this Act, and for customers that elect hourly service from the utility pursuant to Section 16-107 of this Act, provided those customers have not been declared competitive. This requirement commences June 1, 2008 and continues for 10 years.
(d) Notwithstanding the requirements of subsections (b) and (c) of this Section, an electric utility shall reduce the amount of energy efficiency and demand-response measures implemented over a 3-year planning period by an amount necessary to limit the estimated average annual increase in the amounts paid by retail customers in connection with electric service due to the cost of those measures to:
(1) in 2008, no more than 0.5% of the amount paid per     kilowatthour by those customers during the year ending May 31, 2007;
(2) in 2009, the greater of an additional 0.5% of the     amount paid per kilowatthour by those customers during the year ending May 31, 2008 or 1% of the amount paid per kilowatthour by those customers during the year ending May 31, 2007;
(3) in 2010, the greater of an additional 0.5% of the     amount paid per kilowatthour by those customers during the year ending May 31, 2009 or 1.5% of the amount paid per kilowatthour by those customers during the year ending May 31, 2007;
(4) in 2011, the greater of an additional 0.5% of the     amount paid per kilowatthour by those customers during the year ending May 31, 2010 or 2% of the amount paid per kilowatthour by those customers during the year ending May 31, 2007; and
(5) thereafter, the amount of energy efficiency and     demand-response measures implemented for any single year shall be reduced by an amount necessary to limit the estimated average net increase due to the cost of these measures included in the amounts paid by eligible retail customers in connection with electric service to no more than the greater of  2.015% of the amount paid per kilowatthour by those customers during the year ending May 31, 2007 or the incremental amount per kilowatthour paid for these measures in 2011.
No later than June 30, 2011, the Commission shall review the limitation on the amount of energy efficiency and demand-response measures implemented pursuant to this Section and report to the General Assembly its findings as to whether that limitation unduly constrains the procurement of energy efficiency and demand-response measures.
(e) Electric utilities shall be responsible for overseeing the design, development, and filing of energy efficiency and demand-response plans with the Commission. Electric utilities shall implement 100% of the demand-response measures in the plans. Electric utilities shall implement 75% of the energy efficiency measures approved by the Commission, and may, as part of that  implementation, outsource various aspects of program development and implementation. The remaining 25% of those energy efficiency measures approved by the Commission shall be implemented by the Department of Commerce and Economic Opportunity, and must be designed in conjunction with the utility and the filing process. The Department may outsource development and implementation of energy efficiency measures. A minimum of 10% of the entire portfolio of cost-effective energy efficiency measures shall be procured from units of local government, municipal corporations, school districts, and community college districts. The Department shall coordinate the implementation of these measures.
The apportionment of the dollars to cover the costs to implement the Department's share of the portfolio of energy efficiency measures shall be made to the Department once the Department has  executed rebate agreements, grants, or contracts for energy efficiency measures and provided supporting documentation for those rebate agreements,  grants, and contracts to the utility. The Department is authorized to adopt any rules necessary and prescribe procedures in order to ensure compliance by applicants in carrying out the purposes of rebate agreements for energy efficiency measures implemented by the Department made under this Section.
The details of the measures implemented by the Department shall be submitted by the Department to the Commission in connection with the utility's filing regarding the energy efficiency and demand-response measures that the utility implements.
A utility providing approved energy efficiency and demand-response measures in the State shall be permitted to recover costs of those measures through an automatic adjustment clause tariff filed with and approved by the Commission. The tariff shall be established outside the context of a general rate case. Each year the Commission shall initiate a review to reconcile any amounts collected with the actual costs and to determine the required adjustment to the annual tariff factor to match annual expenditures.
Each utility shall include, in its recovery of costs, the costs estimated for both the utility's and the Department's implementation of energy efficiency and demand-response measures. Costs collected by the utility for measures implemented by the Department shall be submitted to the Department pursuant to Section 605-323 of the Civil Administrative Code of Illinois, shall be deposited into the Energy Efficiency Portfolio Standards Fund, and  shall be used by the Department solely for the purpose of implementing these measures. A utility shall not be required to advance any moneys to the Department but only to forward such funds as it has collected. The Department shall report to the Commission on an annual basis regarding the costs actually incurred by the Department in the implementation of the measures. Any changes to the costs of energy efficiency measures as a result of plan modifications shall be appropriately reflected in amounts recovered by the utility and turned over to the Department.
The portfolio of measures, administered by both the utilities and the Department, shall, in combination, be designed to achieve the annual savings targets described in subsections (b) and (c) of this Section, as modified by subsection (d) of this Section.
The utility and the Department shall agree upon a reasonable portfolio of measures and determine the measurable corresponding percentage of the savings goals associated with measures implemented by the utility or Department.
No utility shall be assessed a penalty under subsection (f) of this Section for failure to make a timely filing if that  failure is the result of a lack of agreement with the Department with respect to the allocation of responsibilities or related costs or target assignments. In that  case, the Department and the utility shall file their respective plans with the Commission and the Commission shall determine an appropriate division of measures and programs that meets the requirements of this Section.
If the Department is unable to meet incremental annual performance goals for the portion of the portfolio implemented by the Department, then the utility and the Department shall jointly submit a modified filing to the Commission explaining the performance shortfall and recommending an appropriate course going forward, including any program modifications that may be appropriate in light of the evaluations conducted under item (7) of subsection (f) of this Section. In this case, the utility obligation to collect the Department's costs and turn over those funds to the Department under this subsection (e) shall continue only if the Commission approves the modifications to the plan proposed by the Department.
(f) No later than November 15, 2007, each electric utility shall file an energy efficiency and demand-response plan with the Commission to meet the energy efficiency and demand-response standards for 2008 through 2010. No later than October 1, 2010, each electric utility shall file an energy efficiency and demand-response plan with the Commission to meet the energy efficiency and demand-response standards for 2011 through 2013. Every 3 years thereafter, each electric utility shall file, no later than September 1, an energy efficiency  and demand-response plan with the Commission. If a utility does not file such a plan by September 1 of an applicable year, it shall face a penalty of $100,000 per day until the plan is filed. Each utility's plan shall set forth the utility's proposals to meet the utility's portion of the energy efficiency standards identified in subsection (b) and the demand-response standards identified in subsection (c) of this Section as modified by subsections (d) and (e), taking into account the unique circumstances of the utility's service territory. The Commission shall seek public comment on the utility's plan and shall issue an order approving or disapproving each plan within 5 months after its submission. If the Commission disapproves a plan, the Commission shall, within 30 days, describe in detail the reasons for the disapproval and describe a path by which the utility may file a revised draft of the plan to address the Commission's concerns satisfactorily. If the utility does not refile with the Commission within 60 days, the utility shall be subject to penalties at a rate of $100,000 per day until the plan is filed. This process shall continue, and penalties shall accrue, until the utility has successfully filed a portfolio of energy efficiency and demand-response measures. Penalties shall be deposited into the Energy Efficiency Trust Fund. In submitting proposed energy efficiency and demand-response plans and funding levels to meet the savings goals adopted by this Act the utility shall:
(1) Demonstrate that its proposed energy efficiency     and demand-response measures will achieve the requirements that are identified in subsections (b) and (c) of this Section, as modified by subsections (d) and (e).
(2) Present specific proposals to implement new     building and appliance standards that have been placed into effect.
(3) Present estimates of the total amount paid for     electric service expressed on a per kilowatthour basis associated with the proposed portfolio of measures designed to meet the requirements that are identified in subsections (b) and (c) of this Section, as modified by subsections (d) and (e).
(4) Coordinate with the Department to present a     portfolio of energy efficiency measures proportionate to the share of total annual utility revenues in Illinois from households at or below 150% of the poverty level.  The energy efficiency programs shall be targeted to households with incomes at or below 80% of area median income.
(5) Demonstrate that its overall portfolio of energy     efficiency  and demand-response measures, not including programs covered by item (4) of this subsection (f), are cost-effective using the total resource cost test and represent a diverse cross-section of opportunities for customers of all rate classes to participate in the programs.
(6) Include a proposed cost-recovery tariff mechanism     to fund the proposed energy efficiency and demand-response measures and to ensure the recovery of the prudently and reasonably incurred costs of Commission-approved programs.
(7) Provide for an annual independent evaluation of     the performance of the cost-effectiveness of the utility's portfolio of measures and the Department's portfolio of measures, as well as a full review of the 3-year results of the broader net program impacts and, to the extent practical, for adjustment of the measures on a going-forward basis as a result of the evaluations. The resources dedicated to evaluation shall not exceed 3% of portfolio resources in any given year.
(g) No more than 3% of energy efficiency and demand-response program revenue may be allocated for demonstration of breakthrough equipment and devices.
(h) This Section does not apply to an electric utility that on December 31, 2005 provided electric service to fewer than 100,000 customers in Illinois.
(i) If, after 2 years, an electric utility fails to meet the efficiency standard specified in subsection (b) of this Section, as modified by subsections (d) and (e), it shall make a contribution to the Low-Income Home Energy Assistance Program. The combined total liability for failure to meet the goal shall be $1,000,000, which shall be assessed as follows: a large electric utility shall pay $665,000, and a medium electric utility shall pay $335,000. If, after 3 years, an electric utility fails to meet the efficiency standard specified in subsection (b) of this Section, as modified by subsections (d) and (e), it shall make a contribution to the Low-Income Home Energy Assistance Program. The combined total liability for failure to meet the goal shall be $1,000,000, which shall be assessed as follows: a large electric utility shall pay $665,000, and a medium electric utility shall pay $335,000. In addition, the responsibility for implementing the energy efficiency measures of the utility making the  payment shall be transferred to the Illinois Power Agency if, after 3 years, or in any subsequent 3-year period, the utility fails to meet the efficiency standard specified in subsection (b) of this Section, as modified by subsections (d) and (e). The Agency shall implement a competitive procurement program to procure resources necessary to meet the standards specified in this Section as modified by subsections (d) and (e), with costs for those resources to be recovered in the same manner as products purchased through the procurement plan as provided in Section 16-111.5. The Director shall implement this requirement in connection with the procurement plan as provided in Section 16-111.5.
For purposes of this Section, (i) a "large electric utility" is an electric utility that, on December 31, 2005, served more than 2,000,000 electric customers in Illinois; (ii) a "medium electric utility" is an electric utility that, on December 31, 2005, served 2,000,000 or fewer but more than 100,000 electric customers in Illinois; and (iii) Illinois electric utilities that are affiliated by virtue of a common parent company are considered a single electric utility.
(j) If, after 3 years, or any subsequent 3-year period, the Department fails to implement the Department's share of energy efficiency measures required by the standards in subsection (b), then the Illinois Power Agency may assume responsibility for and control of the Department's share of the required energy efficiency measures. The Agency shall implement a competitive procurement program to procure resources necessary to meet the standards  specified in this Section, with the costs of these resources to be recovered in the same manner as provided for the Department in this Section.
(k) No electric utility shall be deemed to have failed to meet the energy efficiency standards to the extent any such failure is due to a failure of the Department or the Agency.
(l)(1) The energy efficiency and demand-response plans of electric utilities serving more than 500,000 retail customers in the State that were approved by the Commission on or before the effective date of this amendatory Act of the 99th General Assembly for the period June 1, 2014 through May 31, 2017 shall continue to be in force and effect through December 31, 2017 so that the energy efficiency programs set forth in those plans continue to be offered during the period June 1, 2017 through December 31, 2017.  Each such utility is authorized to increase, on a pro rata basis, the energy savings goals and budgets approved in its plan to reflect the additional 7 months of the plan's operation, provided that such increase shall also incorporate reductions to goals and budgets to reflect the proportion of the utility's load attributable to customers who are exempt from this Section under subsection (m) of this Section.
(2)     If an electric utility serving more than 500,000 retail customers in the State filed with the Commission, under subsection (f) of this Section, its proposed energy efficiency and demand-response plan for the period June 1, 2017 through May 31, 2020, and the Commission has not yet entered its final order approving such plan on or before the effective date of this amendatory Act of the 99th General Assembly, then the utility shall file a notice of withdrawal with the Commission, following such effective date, to withdraw the proposed energy efficiency and demand-response plan.  Upon receipt of such notice, the Commission shall dismiss with prejudice any docket that had been initiated to investigate such plan, and the plan and the record related thereto shall not be the subject of any further hearing, investigation, or proceeding of any kind.
(3)      For those electric utilities that serve more than 500,000 retail customers in the State, this amendatory Act of the 99th General Assembly preempts and supersedes any orders entered by the Commission that approved such utilities' energy efficiency and demand response plans for the period commencing June 1, 2017 and ending May 31, 2020.  Any such orders shall be void, and the provisions of paragraph (1) of this subsection (l) shall apply.
(m)   Notwithstanding anything to the contrary, after May 31, 2017, this Section does not apply to any retail customers of an electric utility that serves more than 3,000,000 retail customers in the State and whose total highest 30 minute demand was more than 10,000 kilowatts, or any retail customers of an electric utility that serves less than 3,000,000 retail customers but more than 500,000 retail customers in the State and whose total highest 15 minute demand was more than 10,000 kilowatts. For purposes of this subsection (m), "retail customer" has the meaning set forth in Section 16-102 of this Act.  The criteria for determining whether this subsection (m) is applicable to a retail customer shall be based on the 12 consecutive billing periods prior to the start of the first year of each such multi-year plan.
(Source: P.A. 98-90, eff. 7-15-13; 99-906, eff. 6-1-17.)
(220 ILCS 5/8-103A)
Sec. 8-103A. Energy efficiency analysis. Beginning in 2013, an electric utility subject to the requirements of Section 8-103 of this Act shall include in its energy efficiency and demand-response plan submitted pursuant to subsection (f) of Section 8-103 an analysis of additional cost-effective energy efficiency measures that could be implemented, by customer class, absent the limitations set forth in subsection (d) of Section 8-103. In seeking public comment on the electric utility's plan pursuant to subsection (f) of Section 8-103, the Commission shall include, beginning in 2013, the assessment of additional cost-effective energy efficiency measures submitted pursuant to this Section. For purposes of this Section, the term "energy efficiency" shall have the meaning set forth in Section 1-10 of the Illinois Power Agency Act, and the term "cost-effective" shall have the meaning set forth in subsection (a) of Section 8-103 of this Act.
(Source: P.A. 97-616, eff. 10-26-11.)
(220 ILCS 5/8-103B)
Sec. 8-103B. Energy efficiency and demand-response measures.
(a) It is the policy of the State that electric utilities are required to use cost-effective energy efficiency and demand-response measures to reduce delivery load. Requiring investment in cost-effective energy efficiency and demand-response measures will reduce direct and indirect costs to consumers by decreasing environmental impacts and by avoiding or delaying the need for new generation, transmission, and distribution infrastructure. It serves the public interest to allow electric utilities to recover costs for reasonably and prudently incurred expenditures for energy efficiency and demand-response measures. As used in this Section, "cost-effective" means that the measures satisfy the total resource cost test. The low-income measures described in subsection (c) of this Section shall not be required to meet the total resource cost test. For purposes of this Section, the terms "energy-efficiency", "demand-response", "electric utility", and "total resource cost test" have the meanings set forth in the Illinois Power Agency Act. "Black, indigenous, and people of color" and "BIPOC" means people who are members of the groups described in subparagraphs (a) through (e) of paragraph (A) of subsection (1) of Section 2 of the Business Enterprise for Minorities, Women, and Persons with Disabilities Act.
(a-5)  This Section applies to electric utilities serving more than 500,000 retail customers in the State for those multi-year plans commencing after December 31, 2017.
(b)  For purposes of this Section, electric utilities subject to this Section that serve more than 3,000,000 retail customers in the State shall be deemed to have achieved a cumulative persisting annual savings of 6.6% from energy efficiency measures and programs implemented during the period beginning January 1, 2012  and ending December 31, 2017, which percent is based on the deemed average weather normalized sales of electric power and energy during calendar years 2014, 2015, and 2016 of 88,000,000 MWhs.  For the purposes of this subsection (b) and subsection (b-5), the 88,000,000 MWhs of deemed electric power and energy sales shall be reduced by the number of MWhs equal to the sum of the annual consumption of customers that have opted out of subsections (a) through (j) of this Section under paragraph (1) of subsection (l) of this Section, as averaged across the calendar years 2014, 2015, and 2016. After 2017, the deemed value of cumulative persisting annual savings from energy efficiency measures and programs implemented during the period beginning January 1, 2012 and ending December 31, 2017, shall be reduced each year, as follows, and the applicable value shall be applied to and count toward the utility's achievement of the cumulative persisting annual savings goals set forth in subsection (b-5):
(1) 5.8% deemed cumulative persisting annual savings     for the year ending December 31, 2018;
(2) 5.2% deemed cumulative persisting annual savings     for the year ending December 31, 2019;
(3) 4.5% deemed cumulative persisting annual savings     for the year ending December 31, 2020;
(4) 4.0% deemed cumulative persisting annual savings     for the year ending December 31, 2021;
(5) 3.5% deemed cumulative persisting annual savings     for the year ending December 31, 2022;
(6) 3.1% deemed cumulative persisting annual savings     for the year ending December 31, 2023;
(7) 2.8% deemed cumulative persisting annual savings     for the year ending December 31, 2024;
(8) 2.5% deemed cumulative persisting annual savings     for the year ending December 31, 2025;
(9) 2.3% deemed cumulative persisting annual savings     for the year ending December 31, 2026;
(10)  2.1% deemed cumulative persisting annual     savings for the year ending December 31, 2027;
(11) 1.8% deemed cumulative persisting annual savings     for the year ending December 31, 2028;
(12) 1.7% deemed cumulative persisting annual savings     for the year ending December 31, 2029;
(13) 1.5% deemed cumulative persisting annual savings     for the year ending December 31, 2030;
(14) 1.3% deemed cumulative persisting annual savings     for the year ending December 31, 2031;
(15) 1.1% deemed cumulative persisting annual savings     for the year ending December 31, 2032;
(16) 0.9% deemed cumulative persisting annual savings     for the year ending December 31, 2033;
(17) 0.7% deemed cumulative persisting annual savings     for the year ending December 31, 2034;
(18) 0.5% deemed cumulative persisting annual savings     for the year ending December 31, 2035;
(19) 0.4% deemed cumulative persisting annual savings     for the year ending December 31, 2036;
(20) 0.3% deemed cumulative persisting annual savings     for the year ending December 31, 2037;
(21) 0.2% deemed cumulative persisting annual savings     for the year ending December 31, 2038;
(22) 0.1% deemed cumulative persisting annual savings     for the year ending December 31, 2039; and
(23) 0.0% deemed cumulative persisting annual savings     for the year ending December 31, 2040 and all subsequent years.
For purposes of this Section, "cumulative persisting annual savings" means the total electric energy savings in a given year from measures installed in that year or in previous years, but no earlier than January 1, 2012, that are still operational and providing savings in that year because the measures have not yet reached the end of their useful lives.
(b-5) Beginning in 2018, electric utilities subject to this Section that serve more than 3,000,000 retail customers in the State shall achieve the following cumulative persisting annual savings goals, as modified by subsection (f) of this Section and as compared to the deemed baseline of 88,000,000 MWhs of electric power and energy sales set forth in subsection (b), as reduced by the number of MWhs equal to the sum of the annual consumption of customers that have opted out of subsections (a) through (j) of this Section under paragraph (1) of subsection (l) of this Section as averaged across the calendar years 2014, 2015, and 2016, through the implementation of energy efficiency measures during the applicable year and in prior years, but no earlier than January 1, 2012:
(1) 7.8% cumulative persisting annual savings for the     year ending December 31, 2018;
(2) 9.1% cumulative persisting annual savings for the     year ending December 31, 2019;
(3) 10.4% cumulative persisting annual savings for     the year ending December 31, 2020;
(4) 11.8% cumulative persisting annual savings for     the year ending December 31, 2021;
(5) 13.1% cumulative persisting annual savings for     the year ending December 31, 2022;
(6) 14.4% cumulative persisting annual savings for     the year ending December 31, 2023;
(7) 15.7% cumulative persisting annual savings for     the year ending December 31, 2024;
(8) 17% cumulative persisting annual savings for the     year ending December 31, 2025;
(9) 17.9% cumulative persisting annual savings for     the year ending December 31, 2026;
(10)  18.8% cumulative persisting annual savings for     the year ending December 31, 2027;
(11) 19.7% cumulative persisting annual savings for     the year ending December 31, 2028;
(12) 20.6% cumulative persisting annual savings for     the year ending December 31, 2029; and
(13) 21.5% cumulative persisting annual savings for     the year ending December 31, 2030.
No later than December 31, 2021, the Illinois Commerce Commission shall establish additional cumulative persisting annual savings goals for the years 2031 through 2035. No later than December 31, 2024, the Illinois Commerce Commission shall establish additional cumulative persisting annual savings goals for the years 2036 through 2040. The Commission shall also establish additional cumulative persisting annual savings goals every 5 years thereafter to ensure that utilities always have goals that extend at least 11 years into the future. The cumulative persisting annual savings goals beyond the year 2030 shall increase by 0.9 percentage points per year, absent a Commission decision to initiate a proceeding to consider establishing goals that increase by more or less than that amount. Such a proceeding must be conducted in accordance with the procedures described in subsection (f) of this Section. If such a proceeding is initiated, the cumulative persisting annual savings goals established by the Commission through that proceeding shall reflect the Commission's best estimate of the maximum amount of additional savings that are forecast to be cost-effectively achievable unless such best estimates would result in goals that represent less than 0.5 percentage point annual increases in total cumulative persisting annual savings. The Commission may only establish goals that represent less than 0.5 percentage point annual increases in cumulative persisting annual savings if it can demonstrate, based on clear and convincing evidence and through independent analysis, that 0.5 percentage point increases are not cost-effectively achievable. The Commission shall inform its decision based on an energy efficiency potential study that conforms to the requirements of this Section.
(b-10) For purposes of this Section, electric utilities subject to this Section that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State shall be deemed to have achieved a cumulative persisting annual savings of 6.6% from energy efficiency measures and programs implemented during the period beginning January 1, 2012 and ending December 31, 2017, which is based on the deemed average weather normalized sales of electric power and energy during calendar years 2014, 2015, and 2016 of 36,900,000 MWhs. For the purposes of this subsection (b-10) and subsection (b-15), the 36,900,000 MWhs of deemed electric power and energy sales shall be reduced by the number of MWhs equal to the sum of the annual consumption of customers that have opted out of subsections (a) through (j) of this Section under paragraph (1) of subsection (l) of this Section, as averaged across the calendar years 2014, 2015, and 2016. After 2017, the deemed value of cumulative persisting annual savings from energy efficiency measures and programs implemented during the period beginning January 1, 2012 and ending December 31, 2017, shall be reduced each year, as follows, and the applicable value shall be applied to and count toward the utility's achievement of the cumulative persisting annual savings goals set forth in subsection (b-15):
(1) 5.8% deemed cumulative persisting annual savings     for the year ending December 31, 2018;
(2) 5.2% deemed cumulative persisting annual savings     for the year ending December 31, 2019;
(3) 4.5% deemed cumulative persisting annual savings     for the year ending December 31, 2020;
(4) 4.0% deemed cumulative persisting annual savings     for the year ending December 31, 2021;
(5) 3.5% deemed cumulative persisting annual savings     for the year ending December 31, 2022;
(6) 3.1% deemed cumulative persisting annual savings     for the year ending December 31, 2023;
(7) 2.8% deemed cumulative persisting annual savings     for the year ending December 31, 2024;
(8) 2.5% deemed cumulative persisting annual savings     for the year ending December 31, 2025;
(9) 2.3% deemed cumulative persisting annual savings     for the year ending December 31, 2026;
(10)  2.1% deemed cumulative persisting annual     savings for the year ending December 31, 2027;
(11) 1.8% deemed cumulative persisting annual savings     for the year ending December 31, 2028;
(12) 1.7% deemed cumulative persisting annual savings     for the year ending December 31, 2029;
(13) 1.5% deemed cumulative persisting annual savings     for the year ending December 31, 2030;
(14) 1.3% deemed cumulative persisting annual savings     for the year ending December 31, 2031;
(15) 1.1% deemed cumulative persisting annual savings     for the year ending December 31, 2032;
(16) 0.9% deemed cumulative persisting annual savings     for the year ending December 31, 2033;
(17) 0.7% deemed cumulative persisting annual savings     for the year ending December 31, 2034;
(18) 0.5% deemed cumulative persisting annual savings     for the year ending December 31, 2035;
(19) 0.4% deemed cumulative persisting annual savings     for the year ending December 31, 2036;
(20) 0.3% deemed cumulative persisting annual savings     for the year ending December 31, 2037;
(21) 0.2% deemed cumulative persisting annual savings     for the year ending December 31, 2038;
(22) 0.1% deemed cumulative persisting annual savings     for the year ending December 31, 2039; and
(23) 0.0% deemed cumulative persisting annual savings     for the year ending December 31, 2040 and all subsequent years.
(b-15) Beginning in 2018, electric utilities subject to this Section that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State shall achieve the following cumulative persisting annual savings goals, as modified by subsection (b-20) and subsection (f) of this Section and as compared to the deemed baseline as reduced by the number of MWhs equal to the sum of the annual consumption of customers that have opted out of subsections (a) through (j) of this Section under paragraph (1) of subsection (l) of this Section as averaged across the calendar years 2014, 2015, and 2016, through the implementation of energy efficiency measures during the applicable year and in prior years, but no earlier than January 1, 2012:
(1) 7.4% cumulative persisting annual savings for the     year ending December 31, 2018;
(2) 8.2% cumulative persisting annual savings for the     year ending December 31, 2019;
(3) 9.0% cumulative persisting annual savings for the     year ending December 31, 2020;
(4) 9.8% cumulative persisting annual savings for the     year ending December 31, 2021;
(5) 10.6% cumulative persisting annual savings for     the year ending December 31, 2022;
(6) 11.4% cumulative persisting annual savings for     the year ending December 31, 2023;
(7) 12.2% cumulative persisting annual savings for     the year ending December 31, 2024;
(8) 13% cumulative persisting annual savings for the     year ending December 31, 2025;
(9) 13.6% cumulative persisting annual savings for     the year ending December 31, 2026;
(10)  14.2% cumulative persisting annual savings for     the year ending December 31, 2027;
(11) 14.8% cumulative persisting annual savings for     the year ending December 31, 2028;
(12) 15.4% cumulative persisting annual savings for     the year ending December 31, 2029; and
(13) 16% cumulative persisting annual savings for the     year ending December 31, 2030.
No later than December 31, 2021, the Illinois Commerce Commission shall establish additional cumulative persisting annual savings goals for the years 2031 through 2035. No later than December 31, 2024, the Illinois Commerce Commission shall establish additional cumulative persisting annual savings goals for the years 2036 through 2040. The Commission shall also establish additional cumulative persisting annual savings goals every 5 years thereafter to ensure that utilities always have goals that extend at least 11 years into the future. The cumulative persisting annual savings goals beyond the year 2030 shall increase by 0.6 percentage points per year, absent a Commission decision to initiate a proceeding to consider establishing goals that increase by more or less than that amount. Such a proceeding must be conducted in accordance with the procedures described in subsection (f) of this Section. If such a proceeding is initiated, the cumulative persisting annual savings goals established by the Commission through that proceeding shall reflect the Commission's best estimate of the maximum amount of additional savings that are forecast to be cost-effectively achievable unless such best estimates would result in goals that represent less than 0.4 percentage point annual increases in total cumulative persisting annual savings. The Commission may only establish goals that represent less than 0.4 percentage point annual increases in cumulative persisting annual savings if it can demonstrate, based on clear and convincing evidence and through independent analysis, that 0.4 percentage point increases are not cost-effectively achievable. The Commission shall inform its decision based on an energy efficiency potential study that conforms to the requirements of this Section.
(b-20)  Each electric utility subject to this Section may include cost-effective voltage optimization measures in its plans submitted under subsections (f) and (g) of this Section, and the costs incurred by a utility to implement the measures under a Commission-approved plan shall be recovered under the provisions of Article IX or Section 16-108.5 of this Act. For purposes of this Section, the measure life of voltage optimization measures shall be 15 years. The measure life period is independent of the depreciation rate of the voltage optimization assets deployed. Utilities may claim savings from voltage optimization on circuits for more than 15 years if they can demonstrate that they have made additional investments necessary to enable voltage optimization savings to continue beyond 15 years.  Such demonstrations must be subject to the review of independent evaluation.
Within 270 days after June 1, 2017 (the effective date of Public Act 99-906), an electric utility that serves less than 3,000,000 retail customers but more than 500,000 retail customers in the State shall file a plan with the Commission that identifies the cost-effective voltage optimization investment the electric utility plans to undertake through December 31, 2024.  The Commission, after notice and hearing, shall approve or approve with modification the plan within 120 days after the plan's filing and, in the order approving or approving with modification the plan, the Commission shall adjust the applicable cumulative persisting annual savings goals set forth in subsection (b-15) to reflect any amount of cost-effective energy savings approved by the Commission that is greater than or less than the following cumulative persisting annual savings values attributable to voltage optimization for the applicable year:
(1) 0.0% of cumulative persisting annual savings for     the year ending December 31, 2018;
(2) 0.17% of cumulative persisting annual savings for     the year ending December 31, 2019;
(3) 0.17% of cumulative persisting annual savings for     the year ending December 31, 2020;
(4) 0.33% of cumulative persisting annual savings for     the year ending December 31, 2021;
(5) 0.5% of cumulative persisting annual savings for     the year ending December 31, 2022;
(6) 0.67% of cumulative persisting annual savings for     the year ending December 31, 2023;
(7) 0.83% of cumulative persisting annual savings for     the year ending December 31, 2024; and
(8) 1.0% of cumulative persisting annual savings for     the year ending December 31, 2025 and all subsequent years.
(b-25) In the event an electric utility jointly offers an energy efficiency measure or program with a gas utility under plans approved under this Section and Section 8-104 of this Act, the electric utility may continue offering the program, including the gas energy efficiency measures, in the event the gas utility discontinues funding the program.  In that event, the energy savings value associated with such other fuels shall be converted to electric energy savings on an equivalent Btu basis for the premises. However, the electric utility shall prioritize programs for low-income residential customers to the extent practicable.  An electric utility may recover the costs of offering the gas energy efficiency measures under this subsection  (b-25).
For those energy efficiency measures or programs that save both electricity and other fuels but are not jointly offered with a gas utility under plans approved under this Section and Section 8-104 or not offered with an affiliated gas utility under paragraph (6) of subsection (f) of Section 8-104 of this Act, the electric utility may count savings of fuels other than electricity toward the achievement of its annual savings goal, and the energy savings value associated with such other fuels shall be converted to electric energy savings on an equivalent Btu basis at the premises.
In no event shall more than 10% of each year's applicable annual total savings requirement as defined in paragraph (7.5) of subsection (g) of this Section be met through savings of fuels other than electricity.
(b-27) Beginning in 2022, an electric utility may offer and promote measures that electrify space heating, water heating, cooling, drying, cooking, industrial processes, and other building and industrial end uses that would otherwise be served by combustion of fossil fuel at the premises, provided that the electrification measures reduce total energy consumption at the premises.  The electric utility may count the reduction in energy consumption at the premises toward achievement of its annual savings goals.  The reduction in energy consumption at the premises shall be calculated as the difference between: (A) the reduction in Btu consumption of fossil fuels as a result of electrification, converted to kilowatt-hour equivalents by dividing by 3,412 Btus per kilowatt hour; and (B) the increase in kilowatt hours of electricity consumption resulting from the displacement of fossil fuel consumption as a result of electrification.  An electric utility may recover the costs of offering and promoting electrification measures under this subsection (b-27).
In no event shall electrification savings counted toward each year's applicable annual total savings requirement, as defined in paragraph (7.5) of subsection (g) of this Section, be greater than:
(1)   5% per year for each year from 2022 through     2025;
(2)   10% per year for each year from 2026 through     2029; and
(3)   15% per year for 2030 and all subsequent years.
In addition, a minimum of 25% of all electrification savings counted toward a utility's applicable annual total savings requirement must be from electrification of end uses in low-income housing.  The limitations on electrification savings that may be counted toward a utility's annual savings goals are separate from and in addition to the subsection (b-25) limitations governing the counting of the other fuel savings resulting from efficiency measures and programs.
As part of the annual informational filing to the Commission that is required under paragraph (9) of subsection (g) of this Section, each utility shall identify the specific electrification measures offered under this subsection (b-27); the quantity of each electrification measure that was installed by its customers; the average total cost, average utility cost, average reduction in fossil fuel consumption, and average increase in electricity consumption associated with each electrification measure; the portion of installations of each electrification measure that were in low-income single-family housing, low-income multifamily housing, non-low-income single-family housing, non-low-income multifamily housing, commercial buildings, and industrial facilities; and the quantity of savings associated with each measure category in each customer category that are being counted toward the utility's applicable annual total savings requirement. Prior to installing an electrification measure, the utility shall provide a customer with an estimate of the impact of the new measure on the customer's average monthly electric bill and total annual energy expenses.
(c) Electric utilities shall be responsible for overseeing the design, development, and filing of energy efficiency plans with the Commission and may, as part of that implementation, outsource various aspects of program development and implementation.  A minimum of 10%, for electric utilities that serve more than 3,000,000 retail customers in the State, and a minimum of 7%, for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State, of the utility's entire portfolio funding level for a given year shall be used to procure cost-effective energy efficiency measures from units of local government, municipal corporations, school districts, public housing, and community college districts, provided that a minimum percentage of available funds shall be used to procure energy efficiency from public housing, which percentage shall be equal to public housing's share of public building energy consumption.
The utilities shall also implement energy efficiency measures targeted at low-income households, which, for  purposes of this Section, shall be defined as households at or below 80% of area median income, and expenditures to implement the measures shall be no less than $40,000,000 per year for electric utilities that serve more than 3,000,000 retail customers in the State and no less than $13,000,000 per year for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State. The ratio of spending on efficiency programs targeted at low-income multifamily buildings to spending on efficiency programs targeted at low-income single-family buildings shall be designed to achieve levels of savings from each building type that are approximately proportional to the magnitude of cost-effective lifetime savings potential in each building type. Investment in low-income whole-building weatherization programs shall constitute a minimum of 80% of a utility's total budget specifically dedicated to serving low-income customers.
The utilities shall work to bundle low-income energy efficiency offerings with other programs that serve low-income households to maximize the benefits going to these households. The utilities shall market and implement low-income energy efficiency programs in coordination with low-income assistance programs, the Illinois Solar for All Program, and weatherization whenever practicable. The program implementer shall walk the customer through the enrollment process for any programs for which the customer is  eligible. The utilities shall also pilot targeting customers with high arrearages, high energy intensity (ratio of energy usage divided by home or unit square footage), or energy assistance programs with energy efficiency offerings, and then track reduction in arrearages as a result of the targeting. This targeting and bundling of low-income energy programs shall be offered to both low-income single-family and multifamily customers (owners and residents).
The utilities shall invest in health and safety measures appropriate and necessary for comprehensively weatherizing a home or multifamily building, and shall implement a health and safety fund of at least 15% of the total income-qualified weatherization budget that shall be used for the purpose of making grants for technical assistance, construction, reconstruction, improvement, or repair of buildings to facilitate their participation in the energy efficiency programs targeted at low-income single-family and multifamily households. These funds may also be used for the purpose of making grants for technical assistance, construction, reconstruction, improvement, or repair of the following buildings to facilitate their participation in the energy efficiency programs created by this Section: (1) buildings that are owned or operated by registered 501(c)(3) public charities; and (2) day care centers, day care homes, or group day care homes, as defined under 89 Ill. Adm. Code Part 406, 407, or 408, respectively.
Each electric utility shall assess opportunities to implement cost-effective energy efficiency measures and programs through a public housing authority or authorities located in its service territory.  If such opportunities are identified, the utility shall propose such measures and programs to address the opportunities.  Expenditures to address such opportunities shall be credited toward the minimum procurement and expenditure requirements set forth in this subsection (c).
Implementation of energy efficiency measures and programs targeted at low-income households should be contracted, when it is practicable, to independent third parties that have demonstrated capabilities to serve such households, with a preference for not-for-profit entities and government agencies that have existing relationships with or experience serving low-income communities in the State.
Each electric utility shall develop and implement reporting procedures that address and assist in determining the amount of energy savings that can be applied to the low-income procurement and expenditure requirements set forth in this subsection (c). Each electric utility shall also track the types and quantities or volumes of insulation and air sealing materials, and their associated energy saving benefits, installed in energy efficiency programs targeted at low-income single-family and multifamily households.
The electric utilities shall participate in a low-income energy efficiency accountability committee ("the committee"), which will directly inform the design, implementation, and evaluation of the low-income and public-housing energy efficiency programs.  The committee shall be comprised of the electric utilities subject to the requirements of this Section, the gas utilities subject to the requirements of Section 8-104 of this Act, the utilities' low-income energy efficiency implementation contractors, nonprofit organizations, community action agencies, advocacy groups, State and local governmental agencies, public-housing organizations, and representatives of community-based organizations, especially those living in or working with environmental justice communities and BIPOC communities. The committee shall be composed of 2 geographically differentiated subcommittees: one for stakeholders in northern Illinois and one for stakeholders in central and southern Illinois. The subcommittees shall meet together at least twice per year.
There shall be one statewide leadership committee led by and composed of community-based organizations that are representative of BIPOC and environmental justice communities and that includes equitable representation from BIPOC communities. The leadership committee shall be composed of an equal number of representatives from the 2 subcommittees. The subcommittees shall address specific programs and issues, with the leadership committee convening targeted workgroups as needed. The leadership committee may elect to work with an independent facilitator to solicit and organize feedback, recommendations and meeting participation from a wide variety of community-based stakeholders. If a facilitator is used, they shall be fair and responsive to the needs of all stakeholders involved in the committee.
All committee meetings must be accessible, with rotating locations if meetings are held in-person, virtual participation options, and materials and agendas circulated in advance.
There shall also be opportunities for direct input by committee members outside of committee meetings, such as via individual meetings, surveys, emails and calls, to ensure robust participation by stakeholders with limited capacity and ability to attend committee meetings. Committee meetings shall emphasize opportunities to bundle and coordinate delivery of low-income energy efficiency with other programs that serve low-income communities, such as the Illinois Solar for All Program and bill payment assistance programs. Meetings shall include educational opportunities for stakeholders to learn more about these additional offerings, and the committee shall assist in figuring out the best methods for coordinated delivery and implementation of offerings when serving low-income communities. The committee shall directly and equitably influence and inform utility low-income and public-housing energy efficiency programs and priorities. Participating utilities shall implement recommendations from the committee whenever possible.
Participating utilities shall track and report how input from the committee has led to new approaches and changes in their energy efficiency portfolios.  This reporting shall occur at committee meetings and in quarterly energy efficiency reports to the Stakeholder Advisory Group and Illinois Commerce Commission, and other relevant reporting mechanisms. Participating utilities shall also report on relevant equity data and metrics requested by the committee, such as energy burden data, geographic, racial, and other relevant demographic data on where programs are being delivered and what populations programs are serving.
The Illinois Commerce Commission shall oversee and have relevant staff participate in the committee. The committee shall have a budget of 0.25% of each utility's entire efficiency portfolio funding for a given year.  The budget shall be overseen by the Commission. The budget shall be used to provide grants for community-based organizations serving on the leadership committee, stipends for community-based organizations participating in the committee, grants for community-based organizations to do energy efficiency outreach and education, and relevant meeting needs as determined by the leadership committee. The education and outreach shall include, but is not limited to, basic energy efficiency education, information about low-income energy efficiency programs, and information on the committee's purpose, structure, and activities.
(d) Notwithstanding any other provision of law to the contrary, a utility providing approved energy efficiency measures and, if applicable, demand-response measures in the State shall be permitted to recover all reasonable and prudently incurred costs of those measures from all retail customers, except as provided in subsection (l) of this Section, as follows, provided that nothing in this subsection (d) permits the double recovery of such costs from customers:
(1) The utility may recover its costs through an     automatic adjustment clause tariff filed with and approved by the Commission. The tariff shall be established outside the context of a general rate case. Each year the Commission shall initiate a review to reconcile any amounts collected with the actual costs and to determine the required adjustment to the annual tariff factor to match annual expenditures.  To enable the financing of the incremental capital expenditures, including regulatory assets, for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State, the utility's actual year-end capital structure that includes a common equity ratio, excluding goodwill, of up to and including 50% of the total capital structure shall be deemed reasonable and used to set rates.
(2) A utility may recover its costs through an energy     efficiency formula rate approved by the Commission under a filing under subsections (f) and (g) of this Section, which shall specify the cost components that form the basis of the rate charged to customers with sufficient specificity to operate in a standardized manner and be updated annually with transparent information that reflects the utility's actual costs to be recovered during the applicable rate year, which is the period beginning with the first billing day of January and extending through the last billing day of the following December.  The energy efficiency formula rate shall be implemented through a tariff filed with the Commission under subsections (f) and (g) of this Section that is consistent with the provisions of this paragraph (2) and that shall be applicable to all delivery services customers.  The Commission shall conduct an investigation of the tariff in a manner consistent with the provisions of this paragraph (2), subsections (f) and (g) of this Section, and the provisions of Article IX of this Act to the extent they do not conflict with this paragraph (2). The energy efficiency formula rate approved by the Commission shall remain in effect at the discretion of the utility and shall do the following:
(A) Provide for the recovery of the utility's         actual costs incurred under this Section that are prudently incurred and reasonable in amount consistent with Commission practice and law. The sole fact that a cost differs from that incurred in a prior calendar year or that an investment is different from that made in a prior calendar year shall not imply the imprudence or unreasonableness of that cost or investment.
(B) Reflect the utility's actual year-end capital         structure for the applicable calendar year, excluding goodwill, subject to a determination of prudence and reasonableness consistent with Commission practice and law.  To enable the financing of the incremental capital expenditures, including regulatory assets, for electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State, a participating electric utility's actual year-end capital structure that includes a common equity ratio, excluding goodwill, of up to and including 50% of the total capital structure shall be deemed reasonable and used to set rates.
(C) Include a cost of equity, which shall be         calculated as the sum of the following:
(i) the average for the applicable calendar             year of the monthly average yields of 30-year U.S. Treasury bonds published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication; and
(ii) 580 basis points.
At such time as the Board of Governors of the         Federal Reserve System ceases to include the monthly average yields of 30-year U.S. Treasury bonds in its weekly H.15 Statistical Release or successor publication, the monthly average yields of the U.S. Treasury bonds then having the longest duration published by the Board of Governors in its weekly H.15 Statistical Release or successor publication shall instead be used for purposes of this paragraph (2).
(D) Permit and set forth protocols, subject to a         determination of prudence and reasonableness consistent with Commission practice and law, for the following:
(i) recovery of incentive compensation             expense that is based on the achievement of operational metrics, including metrics related to budget controls, outage duration and frequency, safety, customer service, efficiency and productivity, and environmental compliance; however, this protocol shall not apply if such expense related to costs incurred under this Section is recovered under Article IX or Section 16-108.5 of this Act; incentive compensation expense that is based on net income or an affiliate's earnings per share shall not be recoverable under the  energy efficiency formula rate;
(ii) recovery of pension and other             post-employment benefits expense, provided that such costs are supported by an actuarial study; however, this protocol shall not apply if such expense related to costs incurred under this Section is recovered under Article IX or Section 16-108.5 of this Act;
(iii) recovery of existing regulatory assets             over the periods previously authorized by the Commission;
(iv) as described in subsection (e),             amortization of costs incurred under this Section; and
(v) projected, weather normalized billing             determinants for the applicable rate year.
(E) Provide for an annual reconciliation, as         described in paragraph (3) of this subsection (d), less any deferred taxes related to the reconciliation, with interest at an annual rate of return equal to the utility's weighted average cost of capital, including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return, of the energy efficiency revenue requirement reflected in rates for each calendar year, beginning with the calendar year in which the utility files its energy efficiency formula rate tariff under this paragraph (2), with what the revenue requirement would have been had the actual cost information for the applicable calendar year been available at the filing date.
The utility shall file, together with its tariff, the     projected costs to be incurred by the utility during the rate year under the utility's multi-year plan approved under subsections (f) and (g) of this Section, including, but not limited to, the projected capital investment costs and projected regulatory asset balances with correspondingly updated depreciation and amortization reserves and expense, that shall populate the energy efficiency formula rate and set the initial rates under the formula.
The Commission shall review the proposed tariff in     conjunction with its review of a proposed multi-year plan, as specified in paragraph (5) of subsection (g) of this Section. The review shall be based on the same evidentiary standards, including, but not limited to, those concerning the prudence and reasonableness of the costs incurred by the utility, the Commission applies in a hearing to review a filing for a general increase in rates under Article IX of this Act. The initial rates shall take effect beginning with the January monthly billing period following the Commission's approval.
The tariff's rate design and cost allocation across     customer classes shall be consistent with the utility's automatic adjustment clause tariff in effect on June 1, 2017 (the effective date of Public Act 99-906); however, the Commission may revise the tariff's rate design and cost allocation in subsequent proceedings under paragraph (3) of this subsection (d).
If the energy efficiency formula rate is terminated,     the then current rates shall remain in effect until such time as the energy efficiency costs are incorporated into new rates that are set under this subsection (d) or Article IX of this Act, subject to retroactive rate adjustment, with interest, to reconcile rates charged with actual costs.
(3) The provisions of this paragraph (3) shall only     apply to an electric utility that has elected to file an energy efficiency formula rate under paragraph (2) of this subsection (d).  Subsequent to the Commission's issuance of an order approving the utility's energy efficiency formula rate structure and protocols, and initial rates under paragraph (2) of this subsection (d), the utility shall file, on or before June 1 of each year, with the Chief Clerk of the Commission its updated cost inputs to the energy efficiency formula rate for the applicable rate year and the corresponding new charges, as well as the information described in paragraph (9) of subsection (g) of this Section. Each such filing shall conform to the following requirements and include the following information:
(A) The inputs to the energy efficiency formula         rate for the applicable rate year shall be based on the projected costs to be incurred by the utility during the rate year under the utility's multi-year plan approved under subsections (f) and (g) of this Section, including, but not limited to, projected capital investment costs and projected regulatory asset balances with correspondingly updated depreciation and amortization reserves and expense. The filing shall also include a reconciliation of the energy efficiency revenue requirement that was in effect for the prior rate year (as set by the cost inputs for the prior rate year) with the actual revenue requirement for the prior rate year (determined using a year-end rate base) that uses amounts reflected in the applicable FERC Form 1 that reports the actual costs for the prior rate year.  Any over-collection or under-collection indicated by such reconciliation shall be reflected as a credit against, or recovered as an additional charge to, respectively, with interest calculated at a rate equal to the utility's weighted average cost of capital approved by the Commission for the prior rate year, the charges for the applicable rate year.  Such over-collection or under-collection shall be adjusted to remove any deferred taxes related to the reconciliation, for purposes of calculating interest at an annual rate of return equal to the utility's weighted average cost of capital approved by the Commission for the prior rate year, including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return.  Each reconciliation shall be certified by the participating utility in the same manner that FERC Form 1 is certified. The filing shall also include the charge or credit, if any, resulting from the calculation required by subparagraph (E) of paragraph (2) of this subsection (d).
Notwithstanding any other provision of law to the         contrary, the intent of the reconciliation is to ultimately reconcile both the revenue requirement reflected in rates for each calendar year, beginning with the calendar year in which the utility files its energy efficiency formula rate tariff under paragraph (2) of this subsection (d), with what the revenue requirement determined using a year-end rate base for the applicable calendar year would have been had the actual cost information for the applicable calendar year been available at the filing date.
For purposes of this Section, "FERC Form 1" means         the Annual Report of Major Electric Utilities, Licensees and Others that electric utilities are required to file with the Federal Energy Regulatory Commission under the Federal Power Act, Sections 3, 4(a), 304 and 209, modified as necessary to be consistent with 83 Ill. Adm. Code Part 415 as of May 1, 2011. Nothing in this Section is intended to allow costs that are not otherwise recoverable to be recoverable by virtue of inclusion in FERC Form 1.
(B) The new charges shall take effect beginning         on the first billing day of the following January billing period and remain in effect through the last billing day of the next December billing period regardless of whether the Commission enters upon a hearing under this paragraph (3).
(C) The filing shall include relevant and         necessary data and documentation for the applicable rate year. Normalization adjustments shall not be required.
Within 45 days after the utility files its annual     update of cost inputs to the energy efficiency formula rate, the Commission shall with reasonable notice, initiate a proceeding concerning whether the projected costs to be incurred by the utility and recovered during the applicable rate year, and that are reflected in the inputs to the energy efficiency formula rate, are consistent with the utility's approved multi-year plan under subsections (f) and (g) of this Section and whether the costs incurred by the utility during the prior rate year were prudent and reasonable. The Commission shall also have the authority to investigate the information and data described in paragraph (9) of subsection (g) of this Section, including the proposed adjustment to the utility's return on equity component of its weighted average cost of capital. During the course of the proceeding, each objection shall be stated with particularity and evidence provided in support thereof, after which the utility shall have the opportunity to rebut the evidence. Discovery shall be allowed consistent with the Commission's Rules of Practice, which Rules  of Practice shall be enforced by the Commission or the assigned administrative law judge. The Commission shall apply the same evidentiary standards, including, but not limited to, those concerning the prudence and reasonableness of the costs incurred by the utility, during the proceeding as it would apply in a proceeding to review a filing for a general increase in rates under Article IX of this Act. The Commission shall not, however, have the authority in a proceeding under this paragraph (3) to consider or order any changes to the structure or protocols of the energy efficiency formula rate approved under paragraph (2) of this subsection (d). In a proceeding under this paragraph (3), the Commission shall enter its order no later than the earlier of 195 days after the utility's filing of its annual update of cost inputs to the energy efficiency formula rate or December 15. The utility's proposed return on equity calculation, as described in paragraphs (7) through (9) of subsection (g) of this Section, shall be deemed the final, approved calculation on December 15 of the year in which it is filed unless the Commission enters an order on or before December 15, after notice and hearing, that modifies such calculation consistent with this Section. The Commission's determinations of the prudence and reasonableness of the costs incurred, and determination of such return on equity calculation, for the applicable calendar year shall be final upon entry of the Commission's order and shall not be subject to reopening, reexamination, or collateral attack in any other Commission proceeding, case, docket, order, rule, or regulation; however, nothing in this paragraph (3) shall prohibit a party from petitioning the Commission to rehear or appeal to the courts the order under the provisions of this Act.
(e)

Beginning on June 1, 2017 (the effective date of Public Act 99-906), a utility subject to the requirements of this Section may elect to defer, as a regulatory asset, up to the full amount of its expenditures incurred under this Section for each annual period, including, but not limited to, any expenditures incurred above the funding level set by subsection (f) of this Section for a given year. The total expenditures deferred as a regulatory asset in a given year shall be amortized and recovered over a period that is equal to the weighted average of the energy efficiency measure lives implemented for that year that are reflected in the regulatory asset. The unamortized balance shall be recognized as of December 31 for a given year. The utility shall also earn a return on the total of the unamortized balances of all of the energy efficiency regulatory assets, less any deferred taxes related to those unamortized balances, at an annual rate equal to the utility's weighted average cost of capital that includes, based on a year-end capital structure, the utility's actual cost of debt for the applicable calendar year and a cost of equity, which shall be calculated as the sum of the (i) the average for the applicable calendar year of the monthly average yields of 30-year U.S. Treasury bonds published by the Board of Governors of the Federal Reserve System in its weekly H.15 Statistical Release or successor publication; and (ii) 580 basis points, including a revenue conversion factor calculated to recover or refund all additional income taxes that may be payable or receivable as a result of that return. Capital investment costs shall be depreciated and recovered over their useful lives consistent with generally accepted accounting principles. The weighted average cost of capital shall be applied to the capital investment cost balance, less any accumulated depreciation and accumulated deferred income taxes, as of December 31 for a given year.
When an electric utility creates a regulatory asset under the provisions of this Section, the costs are recovered over a period during which customers also receive a benefit which is in the public interest.  Accordingly, it is the intent of the General Assembly that an electric utility that elects to create a regulatory asset under the provisions of this Section shall recover all of the associated costs as set forth in this Section.  After the Commission has approved the prudence and reasonableness of the costs that comprise the regulatory asset, the electric utility shall be permitted to recover all such costs, and the value and recoverability through rates of the associated regulatory asset shall not be limited, altered, impaired, or reduced.
(f) Beginning in 2017, each electric utility shall file an energy efficiency plan with the Commission to meet the energy efficiency standards for the next applicable multi-year period beginning January 1 of the year following the filing, according to the schedule set forth in paragraphs (1) through (3) of this subsection (f).  If a utility does not file such a plan on or before the applicable filing deadline for the plan, it shall face a penalty of $100,000 per day until the plan is filed.
(1)  No later than 30 days after June 1, 2017 (the     effective date of Public Act 99-906), each electric utility shall file a 4-year energy efficiency plan commencing on January 1, 2018 that is designed to achieve the cumulative persisting annual savings goals specified in paragraphs (1) through (4) of subsection (b-5) of this Section or in paragraphs (1) through (4) of subsection (b-15) of this Section, as applicable, through implementation of energy efficiency measures; however, the goals may be reduced if the utility's expenditures are limited pursuant to subsection (m) of this Section or, for a utility that serves less than 3,000,000 retail customers, if each of the following conditions are met: (A) the plan's analysis and forecasts of the utility's ability to acquire energy savings demonstrate that achievement of such goals is not cost effective; and (B) the amount of energy savings achieved by the utility as determined by the independent  evaluator for the most recent year for which savings have been evaluated preceding the plan filing was less than the average annual amount of savings required to achieve the goals for the applicable 4-year plan period. Except as provided in subsection (m) of this Section, annual increases in cumulative persisting annual savings goals during the applicable 4-year plan period shall not be reduced to amounts that are less than the maximum amount of cumulative persisting annual savings that is forecast to be cost-effectively achievable during the 4-year plan period. The Commission shall review any proposed goal reduction as part of its review and approval of the utility's proposed plan.
(2)  No later than March 1, 2021, each electric     utility shall file a 4-year energy efficiency plan commencing on January 1, 2022 that is designed to achieve the cumulative persisting annual savings goals specified in paragraphs (5) through (8) of subsection (b-5) of this Section or in paragraphs (5) through (8) of subsection (b-15) of this Section, as applicable, through implementation of energy efficiency measures; however, the goals may be reduced if either (1) clear and convincing evidence demonstrates, through independent analysis, that the  expenditure limits in subsection (m) of this Section preclude full achievement of the goals or (2) each of the following conditions are met: (A) the plan's analysis and forecasts of the utility's ability to acquire energy savings demonstrate by clear and convincing evidence and through independent analysis that achievement of such goals is not cost effective; and (B) the amount of energy savings achieved by the utility as determined by the independent  evaluator for the most recent year for which savings have been evaluated preceding the plan filing was less than the average annual amount of savings required to achieve the goals for the applicable 4-year plan period. If there is not clear and convincing evidence that achieving the savings goals specified in paragraph (b-5) or (b-15) of this Section is possible both cost-effectively and within the expenditure limits in subsection (m), such savings goals shall not be reduced. Except as provided in subsection (m) of this Section, annual increases in cumulative persisting annual savings goals during the applicable 4-year plan period shall not be reduced to amounts that are less than the maximum amount of cumulative persisting annual savings that is forecast to be cost-effectively achievable during the 4-year plan period. The Commission shall review any proposed goal reduction as part of its review and approval of the utility's proposed plan.
(3)  No later than March 1, 2025, each electric     utility shall file a 4-year energy efficiency plan commencing on January 1, 2026 that is designed to achieve the cumulative persisting annual savings goals specified in paragraphs (9) through (12) of subsection (b-5) of this Section or in paragraphs (9) through (12) of subsection (b-15) of this Section, as applicable, through implementation of energy efficiency measures; however, the goals may be reduced if either (1) clear and convincing evidence demonstrates, through independent analysis, that the  expenditure limits  in subsection (m) of this Section preclude full achievement of the goals or (2) each of the following conditions are met: (A) the plan's analysis and forecasts of the utility's ability to acquire energy savings demonstrate by clear and convincing evidence and through independent analysis that achievement of such goals is not cost effective; and (B) the amount of energy savings achieved by the utility as determined by the independent evaluator for the most recent year for which savings have  been evaluated preceding the plan filing was less than the average annual amount of savings required to achieve the goals for the applicable 4-year plan period. If there is not clear and convincing evidence that achieving the savings goals specified in paragraphs (b-5) or (b-15) of this Section is possible both cost-effectively and within the expenditure limits in subsection (m), such savings goals shall not be reduced. Except as provided in subsection (m) of this Section, annual increases in cumulative persisting annual savings goals during the applicable 4-year plan period shall not be reduced to amounts that are less than the maximum amount of cumulative persisting annual savings that is forecast to be cost-effectively achievable during the 4-year plan period. The Commission shall review any proposed goal reduction as part of its review and approval of the utility's proposed plan.
(4) No later than March 1, 2029, and every 4 years     thereafter, each electric utility shall file a 4-year energy efficiency plan commencing on January 1, 2030, and every 4 years thereafter, respectively, that is designed to achieve the cumulative persisting annual savings goals established by the Illinois Commerce Commission pursuant to direction of subsections (b-5) and (b-15) of this Section, as applicable, through implementation of energy efficiency measures; however, the goals may be reduced if either (1) clear and convincing evidence and independent analysis demonstrates that the expenditure limits in subsection (m) of this Section preclude full achievement of the goals or (2) each of the following conditions are met: (A) the plan's analysis and forecasts of the utility's ability to acquire energy savings demonstrate by clear and convincing evidence and through independent analysis that achievement of such goals is not cost-effective; and (B) the amount of energy savings achieved by the utility as determined by the independent evaluator for the most recent year for which savings have been evaluated preceding the plan filing was less than the average annual amount of savings required to achieve the goals for the applicable 4-year plan period. If there is not clear and convincing evidence that achieving the savings goals specified in paragraphs (b-5) or (b-15) of this Section is possible both cost-effectively and within the expenditure limits in subsection (m), such savings goals shall not be reduced. Except as provided in subsection (m) of this Section, annual increases in cumulative persisting annual savings goals during the applicable 4-year plan period shall not be reduced to amounts that are less than the maximum amount of cumulative persisting annual savings that is forecast to be cost-effectively achievable during the 4-year plan period. The Commission shall review any proposed goal reduction as part of its review and approval of the utility's proposed plan.
Each utility's plan shall set forth the utility's proposals to meet the energy efficiency standards identified in subsection (b-5) or (b-15), as applicable and as such standards may have been modified under this subsection (f), taking into account the unique circumstances of the utility's service territory. For those plans commencing on January 1, 2018, the Commission shall seek public comment on the utility's plan and shall issue an order approving or disapproving each plan no later than 105 days after June 1, 2017 (the effective date of Public Act 99-906). For those plans commencing after December 31, 2021, the Commission shall seek public comment on the utility's plan and shall issue an order approving or disapproving each plan within 6 months after its submission. If the Commission disapproves a plan, the Commission shall, within 30 days, describe in detail the reasons for the disapproval and describe a path by which the utility may file a revised draft of the plan to address the Commission's concerns satisfactorily. If the utility does not refile with the Commission within 60 days, the utility shall be subject to penalties at a rate of $100,000 per day until the plan is filed. This process shall continue, and penalties shall accrue, until the utility has successfully filed a portfolio of energy efficiency and demand-response measures. Penalties shall be deposited into the Energy Efficiency Trust Fund.
(g) In submitting proposed plans and funding levels under subsection (f) of this Section to meet the savings goals identified in subsection (b-5) or (b-15) of this Section, as applicable, the utility shall:
(1) Demonstrate that its proposed energy efficiency     measures will achieve the applicable requirements that are identified in subsection (b-5) or (b-15) of this Section, as modified by subsection (f) of this Section.
(2) (Blank).
(2.5) Demonstrate consideration of program options     for (A) advancing new building codes, appliance standards, and municipal regulations governing existing and new building efficiency improvements and (B) supporting efforts to improve compliance with new building codes, appliance standards and municipal regulations, as potentially cost-effective means of acquiring energy savings to count toward savings goals.
(3) Demonstrate that its overall portfolio of     measures, not including low-income programs described in subsection (c) of this Section, is cost-effective using the total resource cost test or complies with paragraphs (1) through (3) of subsection (f) of this Section and represents a diverse cross-section of opportunities for customers of all rate classes, other than those customers described in subsection (l) of this Section, to participate in the programs. Individual measures need not be cost effective.
(3.5) Demonstrate that the utility's plan integrates     the delivery of energy efficiency programs with natural gas efficiency programs, programs promoting distributed solar, programs promoting demand response and other efforts to address bill payment issues, including, but not limited to, LIHEAP and the Percentage of Income Payment Plan, to the extent such integration is practical and has the potential to enhance customer engagement, minimize market confusion, or reduce administrative costs.
(4)  Present a third-party energy efficiency     implementation program subject to the following requirements:
(A) beginning with the year commencing January 1,         2019, electric utilities that serve more than 3,000,000 retail customers in the State shall fund third-party energy efficiency programs in an amount that is no less than $25,000,000 per year, and electric utilities that serve less than 3,000,000 retail customers but more than 500,000 retail customers in the State shall fund third-party energy efficiency programs in an amount that is no less than $8,350,000 per year;
(B) during 2018, the utility shall conduct a         solicitation process for purposes of requesting proposals from third-party vendors for those third-party energy efficiency programs to be offered during one or more of the years commencing January 1, 2019, January 1, 2020, and January 1, 2021; for those multi-year plans commencing on January 1, 2022 and January 1, 2026, the utility shall conduct a solicitation process during 2021 and 2025, respectively, for purposes of requesting proposals from third-party vendors for those third-party energy efficiency programs to be offered during one or more years of the respective multi-year plan period; for  each solicitation process, the utility shall identify the sector, technology, or geographical area for which it is seeking requests for proposals; the solicitation process must be either for programs that fill gaps in the utility's program portfolio and for programs that target low-income customers, business sectors, building types, geographies, or other specific parts of its customer base with initiatives that would be more effective at reaching these customer segments than the utilities' programs filed in its energy efficiency plans;
(C) the utility shall propose the bidder         qualifications, performance measurement process, and contract structure, which must include a performance payment mechanism and general terms and conditions; the proposed qualifications, process, and structure shall be subject to Commission approval; and
(D)  the utility shall retain an independent         third party to score the proposals received through the solicitation process described in this paragraph (4), rank them according to their cost per lifetime kilowatt-hours saved, and assemble the portfolio of third-party programs.
The electric utility shall recover all costs     associated with Commission-approved, third-party administered programs regardless of the success of those programs.
(4.5) Implement cost-effective demand-response     measures to reduce peak demand by 0.1% over the prior year for eligible retail customers, as defined in Section 16-111.5 of this Act, and for customers that elect hourly service from the utility pursuant to Section 16-107 of this Act, provided those customers have not been declared competitive.  This requirement continues until December 31, 2026.
(5) Include a proposed or revised cost-recovery     tariff mechanism, as provided for under subsection (d) of this Section, to fund the proposed energy efficiency and demand-response measures and to ensure the recovery of the prudently and reasonably incurred costs of Commission-approved programs.
(6) Provide for an annual independent evaluation of     the performance of the cost-effectiveness of the utility's portfolio of measures, as well as a full review of the multi-year plan results of the broader net program impacts and, to the extent practical, for adjustment of the measures on a going-forward basis as a result of the evaluations. The resources dedicated to evaluation shall not exceed 3% of portfolio resources in any given year.
(7) For electric utilities that serve more than     3,000,000 retail customers in the State:
(A)  Through December 31, 2025, provide for an         adjustment to the return on equity component of the utility's weighted average cost of capital calculated under subsection (d) of this Section:
(i)  If the independent evaluator determines             that the utility achieved a cumulative persisting annual savings that is less than the applicable annual incremental goal, then the return on equity component shall be reduced by a maximum of 200 basis points in the event that the utility achieved no more than 75% of such goal.  If the utility achieved more than 75% of the applicable annual incremental goal but less than 100% of such goal, then the return on equity component shall be reduced by 8 basis points for each percent by which the utility failed to achieve the goal.
(ii)  If the independent evaluator determines             that the utility achieved a cumulative persisting annual savings that is more than the applicable annual incremental goal, then the return on equity component shall be increased by a maximum of 200 basis points in the event that the utility achieved at least 125% of such goal.  If the utility achieved more than 100% of the applicable annual incremental goal but less than 125% of such goal, then the return on equity component shall be increased by 8 basis points for each percent by which the utility achieved above the goal. If the applicable annual incremental goal was reduced under paragraph (1) or (2) of subsection (f) of this Section, then the following adjustments shall be made to the calculations described in this item (ii):
(aa)    the calculation for determining                 achievement that is at least 125% of the applicable annual incremental goal shall use the unreduced applicable annual incremental goal to set the value; and
(bb)   the calculation for determining                 achievement that is less than 125% but more than 100% of the applicable annual incremental goal shall use the reduced applicable annual incremental goal to set the value for 100% achievement of the goal and shall use the unreduced goal to set the value for 125% achievement.  The 8 basis point value shall also be modified, as necessary, so that the 200 basis points are evenly apportioned among each percentage point value between 100% and 125% achievement.
(B) For the period January 1, 2026 through         December 31, 2029 and in all subsequent 4-year periods, provide for an adjustment to the return on equity component of the utility's weighted average cost of capital calculated under subsection (d) of this Section:
(i) If the independent evaluator determines             that the utility achieved a cumulative persisting annual savings that is less than the applicable annual incremental goal, then the return on equity component shall be reduced by a maximum of 200 basis points in the event that the utility achieved no more than 66% of such goal.  If the utility achieved more than 66% of the applicable annual incremental goal but less than 100% of such goal, then the return on equity component shall be reduced by 6 basis points for each percent by which the utility failed to achieve the goal.
(ii) If the independent evaluator determines             that the utility achieved a cumulative persisting annual savings that is more than the applicable annual incremental goal, then the return on equity component shall be increased by a maximum of 200 basis points in the event that the utility achieved at least 134% of such goal.  If the utility achieved more than 100% of the applicable annual incremental goal but less than 134% of such goal, then the return on equity component shall be increased by 6 basis points for each percent by which the utility achieved above the goal. If the applicable annual incremental goal was reduced under paragraph (3) of subsection (f) of this Section, then the following adjustments shall be made to the calculations described in this item (ii):
(aa)   the calculation for determining                 achievement that is at least 134% of the applicable annual incremental goal shall use the unreduced applicable annual incremental goal to set the value; and
(bb)   the calculation for determining                 achievement that is less than 134% but more than 100% of the applicable annual incremental goal shall use the reduced applicable annual incremental goal to set the value for 100% achievement of the goal and shall use the unreduced goal to set the value for 134% achievement.  The 6 basis point value shall also be modified, as necessary, so that the 200 basis points are evenly apportioned among each percentage point value between 100% and 134% achievement.
(C) Notwithstanding the provisions of         subparagraphs (A) and (B) of this paragraph (7), if the applicable annual incremental goal for an electric utility is ever less than 0.6% of deemed average weather normalized sales of electric power and energy during calendar years 2014, 2015, and 2016, an adjustment to the return on equity component of the utility's weighted average cost of capital calculated under subsection (d) of this Section shall be made as follows:
(i) If the independent evaluator determines             that the utility achieved a cumulative persisting annual savings that is less than would have been achieved had the applicable annual incremental goal been achieved, then the return on equity component shall be reduced by a maximum of 200 basis points if the utility achieved no more than 75% of its applicable annual total savings requirement as defined in paragraph (7.5) of this subsection. If the utility achieved more than 75% of the applicable annual total savings requirement but less than 100% of such goal, then the return on equity component shall be reduced by 8 basis points for each percent by which the utility failed to achieve the goal.
(ii) If the independent evaluator determines             that the utility achieved a cumulative persisting annual savings that is more than would have been achieved had the applicable annual incremental goal been achieved, then the return on equity component shall be increased by a maximum of 200 basis points if the utility achieved at least 125% of its applicable annual total savings requirement. If the utility achieved more than 100% of the applicable annual total savings requirement but less than 125% of such goal, then the return on equity component shall be increased by 8 basis points for each percent by which the utility achieved above the applicable annual total savings requirement. If the applicable annual incremental goal was reduced under paragraph (1) or (2) of subsection (f) of this Section, then the following adjustments shall be made to the calculations described in this item (ii):
(aa) the calculation for determining                 achievement that is at least 125% of the applicable annual total savings requirement shall use the unreduced applicable annual incremental goal to set the value; and
(bb) the calculation for determining                 achievement that is less than 125% but more than 100% of the applicable annual total savings requirement shall use the reduced applicable annual incremental goal to set the value for 100% achievement of the goal and shall use the unreduced goal to set the value for 125% achievement. The 8 basis point value shall also be modified, as necessary, so that the 200 basis points are evenly apportioned among each percentage point value between 100% and 125% achievement.
(7.5) For purposes of this Section, the term     "applicable annual incremental goal" means the difference between the cumulative persisting annual savings goal for the calendar year that is the subject of the independent evaluator's determination and the cumulative persisting annual savings goal for the immediately preceding calendar year, as such goals are defined in subsections (b-5) and (b-15) of this Section and as these goals may have been modified as provided for under subsection (b-20) and paragraphs (1) through (3) of subsection (f) of this Section. Under subsections (b), (b-5), (b-10), and (b-15) of this Section, a utility must first replace energy savings from measures that have expired before any progress towards achievement of its applicable annual incremental goal may be counted. Savings may expire because measures installed in previous years have reached the end of their lives, because measures installed in previous years are producing lower savings in the current year than in the previous year, or for other reasons identified by independent evaluators. Notwithstanding anything else set forth in this Section, the difference between the actual annual incremental savings achieved in any given year, including the replacement of energy savings that have expired, and the applicable annual incremental goal shall not affect adjustments to the return on equity for subsequent calendar years under this subsection (g).
In this Section, "applicable annual total savings     requirement" means the total amount of new annual savings that the utility must achieve in any given year to achieve the applicable annual incremental goal. This is equal to the applicable annual incremental goal plus the total new annual savings that are required to replace savings that expired in or at the end of the previous year.
(8) For electric utilities that serve less than     3,000,000 retail customers but more than 500,000 retail customers in the State:
(A) Through December 31, 2025, the applicable         annual incremental goal shall be compared to the annual incremental savings as determined by the independent evaluator.
(i) The return on equity component shall be             reduced by 8 basis points for each percent by which the utility did not achieve 84.4% of the applicable annual incremental goal.
(ii) The return on equity component shall be             increased by 8 basis points for each percent by which the utility exceeded 100% of the applicable annual incremental goal.
(iii) The return on equity component shall             not be increased or decreased if the annual incremental savings as determined by the independent evaluator is greater than 84.4% of the applicable annual incremental goal and less than 100% of the applicable annual incremental goal.
(iv) The return on equity component shall not             be increased or decreased by an amount greater than 200 basis points pursuant to this subparagraph (A).
(B) For the period of January 1, 2026 through         December 31, 2029 and in all subsequent 4-year periods, the applicable annual incremental goal shall be compared to the annual incremental savings as determined by the independent evaluator.
(i) The return on equity component shall be             reduced by 6 basis points for each percent by which the utility did not achieve 100% of the applicable annual incremental goal.
(ii) The return on equity component shall be             increased by 6 basis points for each percent by which the utility exceeded 100% of the applicable annual incremental goal.
(iii) The return on equity component shall             not be increased or decreased by an amount greater than 200 basis points pursuant to this subparagraph (B).
(C) Notwithstanding provisions in subparagraphs         (A) and (B) of paragraph (7) of this subsection, if the applicable annual incremental goal for an electric utility is ever less than 0.6% of deemed average weather normalized sales of electric power and energy during calendar years 2014, 2015 and 2016, an adjustment to the return on equity component of the utility's weighted average cost of capital calculated under subsection (d) of this Section shall be made as follows:
(i) The return on equity component shall be             reduced by 8 basis points for each percent by which the utility did not achieve 100% of the applicable annual total savings requirement.
(ii) The return on equity component shall be             increased by 8 basis points for each percent by which the utility exceeded 100% of the applicable annual total savings requirement.
(iii) The return on equity component shall             not be increased or decreased by an amount greater than 200 basis points pursuant to this subparagraph (C).
(D) If the applicable annual incremental goal was         reduced under paragraph (1), (2), (3), or (4) of subsection (f) of this Section, then the following adjustments shall be made to the calculations described in subparagraphs (A), (B), and (C) of this paragraph (8):
(i) The calculation for determining             achievement that is at least 125% or 134%, as applicable, of the applicable annual incremental goal or the applicable annual total savings requirement, as applicable, shall use the unreduced applicable annual incremental goal to set the value.
(ii) For the period through December 31,             2025, the calculation for determining achievement that is less than 125% but more than 100% of the applicable annual incremental goal or the applicable annual total savings requirement, as applicable, shall use the reduced applicable annual incremental goal to set the value for 100% achievement of the goal and shall use the unreduced goal to set the value for 125% achievement. The 8 basis point value shall also be modified, as necessary, so that the 200 basis points are evenly apportioned among each percentage point value between 100% and 125% achievement.
(iii) For the period of January 1, 2026             through December 31, 2029 and all subsequent 4-year periods, the calculation for determining achievement that is less than 125% or 134%, as applicable, but more than 100% of the applicable annual incremental goal or the applicable annual total savings requirement, as applicable, shall use the reduced applicable annual incremental goal to set the value for 100% achievement of the goal and shall use the unreduced goal to set the value for 125% achievement. The 6 basis-point value or 8 basis-point value, as applicable, shall also be modified, as necessary, so that the 200 basis points are evenly apportioned among each percentage point value between 100% and 125% or between 100% and 134% achievement, as applicable.
(9) The utility shall submit the energy savings data     to the independent evaluator no later than 30 days after the close of the plan year.  The independent evaluator shall determine the cumulative persisting annual savings for a given plan year, as well as an estimate of job impacts and other macroeconomic impacts of the efficiency programs for that year, no later than 120 days after the close of the plan year.  The utility shall submit an informational filing to the Commission no later than 160 days after the close of the plan year that attaches the independent evaluator's final report identifying the cumulative persisting annual savings for the year and calculates, under paragraph (7) or (8) of this subsection (g), as applicable, any resulting change to the utility's return on equity component of the weighted average cost of capital applicable to the next plan year beginning with the January monthly billing period and extending through the December monthly billing period.  However, if the utility recovers the costs incurred under this Section under paragraphs (2) and (3) of subsection (d) of this Section, then the utility shall not be required to submit such informational filing, and shall instead submit the information that would otherwise be included in the informational filing as part of its filing under paragraph (3) of such subsection (d) that is due on or before June 1 of each year.
For those utilities that must submit the     informational filing, the Commission may, on its own motion or by petition, initiate an investigation of such filing, provided, however, that the utility's proposed return on equity calculation shall be deemed the final, approved calculation on December 15 of the year in which it is filed unless the Commission enters an order on or before December 15, after notice and hearing, that modifies such calculation consistent with this Section.
The adjustments to the return on equity component     described in paragraphs (7) and (8) of this subsection (g) shall be applied as described in such paragraphs through a separate tariff mechanism, which shall be filed by the utility under subsections (f) and (g) of this Section.
(9.5) The utility must demonstrate how it will ensure     that program implementation contractors and energy efficiency installation vendors will promote workforce equity and quality jobs.
(9.6) Utilities shall collect data necessary to     ensure compliance with paragraph (9.5) no less than quarterly and shall communicate progress toward compliance with paragraph (9.5) to program implementation contractors and energy efficiency installation vendors no less than quarterly.  Utilities shall work with relevant vendors, providing education, training, and other resources needed to ensure compliance and, where necessary, adjusting or terminating work with vendors that cannot assist with compliance.
(10) Utilities required to implement efficiency     programs under subsections (b-5) and (b-10) shall report annually to the Illinois Commerce Commission and the General Assembly on how hiring, contracting, job training, and other practices related to its energy efficiency programs enhance the diversity of vendors working on such programs.  These reports must include data on vendor and employee diversity, including data on the implementation of paragraphs (9.5) and (9.6).  If the utility is not meeting the requirements of paragraphs (9.5) and (9.6), the utility shall submit a plan to adjust their activities so that they  meet the requirements of paragraphs (9.5) and (9.6) within the following year.
(h) No more than 4% of energy efficiency and demand-response program revenue may be allocated for research, development, or pilot deployment of new equipment or measures. Electric utilities shall work with interested stakeholders to formulate a plan for how these funds should be spent, incorporate statewide approaches for these allocations, and file a 4-year plan that demonstrates that collaboration. If a utility files a request for modified annual energy savings goals with the Commission, then a utility shall forgo spending portfolio dollars on research and development proposals.
(i) When practicable, electric utilities shall incorporate advanced metering infrastructure data into the planning, implementation, and evaluation of energy efficiency measures and programs, subject to the data privacy and confidentiality protections of applicable law.
(j) The independent evaluator shall follow the guidelines and use the savings set forth in Commission-approved energy efficiency policy manuals and technical reference manuals, as each may be updated from time to time.  Until such time as measure life values for energy efficiency measures implemented for low-income households under subsection (c) of this Section are incorporated into such Commission-approved manuals, the low-income measures shall have the same measure life values that are established for same measures implemented in households that are not low-income households.
(k)  Notwithstanding any provision of law to the contrary, an electric utility subject to the requirements of this Section may file a tariff cancelling an automatic adjustment clause tariff in effect under this Section or Section 8-103, which shall take effect no later than one business day after the date such tariff is filed.  Thereafter, the utility shall be authorized to defer and recover its expenditures incurred under this Section through a new tariff authorized under subsection (d) of this Section or in the utility's next rate case under Article IX or Section 16-108.5 of this Act, with interest at an annual rate equal to the utility's weighted average cost of capital as approved by the Commission in such case.   If the utility elects to file a new tariff under subsection (d) of this Section, the utility may file the tariff within 10 days after June 1, 2017 (the effective date of Public Act 99-906), and the cost inputs to such tariff shall be based on the projected costs to be incurred by the utility during the calendar year in which the new tariff is filed and that were not recovered under the tariff that was cancelled as provided for in this subsection.  Such costs shall include those incurred or to be incurred by the utility under its multi-year plan approved under subsections (f) and (g) of this Section, including, but not limited to, projected capital investment costs and projected regulatory asset balances with correspondingly updated depreciation and amortization reserves and expense.  The Commission shall, after notice and hearing, approve, or approve with modification, such tariff and cost inputs no later than 75 days after the utility filed the tariff, provided that such approval, or approval with modification, shall be consistent with the provisions of this Section to the extent they do not conflict with this subsection (k).  The tariff approved by the Commission shall take effect no later than 5 days after the Commission enters its order approving the tariff.
No later than 60 days after the effective date of the tariff cancelling the utility's automatic adjustment clause tariff, the utility shall file a reconciliation that reconciles the moneys collected under its automatic adjustment clause tariff with the costs incurred during the period beginning June 1, 2016 and ending on the date that the electric utility's automatic adjustment clause tariff was cancelled.   In the event the reconciliation reflects an under-collection, the utility shall recover the costs as specified in this subsection (k).  If the reconciliation reflects an over-collection, the utility shall apply the amount of such over-collection as a one-time credit to retail customers' bills.
(l) For the calendar years covered by a multi-year plan
commencing after December 31, 2017, subsections (a) through
(j) of this Section do not apply to eligible large private
energy customers that have chosen to opt out of multi-year
plans consistent with this subsection
(1).
(1) For purposes of this subsection (l), "eligible     large private energy customer" means any retail customers, except for federal, State, municipal, and other public customers, of an electric utility that serves more than 3,000,000 retail customers, except for federal, State, municipal and other public customers, in the State and whose total highest 30 minute demand was more than 10,000 kilowatts, or any retail customers of an electric utility that serves less than 3,000,000 retail customers but more than 500,000 retail customers in the State and whose total highest 15 minute demand was more than 10,000 kilowatts. For purposes of this subsection (l), "retail customer" has the meaning set forth in Section 16-102 of this Act. However, for a business entity with multiple sites located in the State, where at least one of those sites qualifies as an eligible large private energy customer, then any of that business entity's sites, properly identified on a form for notice, shall be considered eligible large private energy customers for the purposes of this subsection (l).  A determination of whether this subsection is applicable to a customer shall be made for each multi-year plan beginning after December 31, 2017. The criteria for determining whether this subsection (l) is applicable to a retail customer shall be based on the 12 consecutive billing periods prior to the start of the first year of each such multi-year plan.
(2) Within 45 days after September 15, 2021 (the     effective date of Public Act 102-662), the Commission shall prescribe the form for notice required for opting out of energy efficiency programs. The notice must be submitted to the retail electric utility 12 months before the next energy efficiency planning cycle. However, within 120 days after the Commission's initial issuance of the form for notice, eligible large private energy customers may submit a form for notice to an electric utility. The form for notice for opting out of energy efficiency programs shall include all of the following:
(A) a statement indicating that the customer has         elected to opt out;
(B) the account numbers for the customer accounts         to which the opt out shall apply;
(C) the mailing address associated with the         customer accounts identified under subparagraph (B);
(D) an American Society of Heating,         Refrigerating, and Air-Conditioning Engineers (ASHRAE) level 2 or higher audit report conducted by an independent third-party expert identifying cost-effective energy efficiency project opportunities that could be invested in over the next 10 years. A retail customer with specialized processes may utilize a self-audit process in lieu of the ASHRAE audit;
(E) a description of the customer's plans to         reallocate the funds toward internal energy efficiency efforts identified in the subparagraph (D) report, including, but not limited to: (i) strategic energy management or other programs, including descriptions of targeted buildings, equipment and operations; (ii) eligible energy efficiency measures; and (iii) expected energy savings, itemized by technology. If the subparagraph (D) audit report identifies that the customer currently utilizes the best available energy efficient technology, equipment, programs, and operations, the customer may provide a statement that more efficient technology, equipment, programs, and operations are not reasonably available as a means of satisfying this subparagraph (E); and
(F) the effective date of the opt out, which will         be the next January 1 following notice of the opt out.
(3) Upon receipt of a properly and timely noticed     request for opt out submitted by an eligible large private energy customer, the retail electric utility shall grant the request, file the request with the Commission and, beginning January 1 of the following year, the opted out customer shall no longer be assessed the costs of the plan and shall be prohibited from participating in that 4-year plan cycle to give the retail utility the certainty to design program plan proposals.
(4) Upon a customer's election to opt out under     paragraphs (1) and (2) of this subsection (l) and commencing on the effective date of said opt out, the account properly identified in the customer's notice under paragraph (2) shall not be subject to any cost recovery and shall not be eligible to participate in, or directly benefit from, compliance with energy efficiency cumulative persisting savings requirements under subsections (a) through (j).
(5) A utility's cumulative persisting annual savings     targets will exclude any opted out load.
(6) The request to opt out is only valid for the     requested plan cycle. An eligible large private energy customer must also request to opt out for future energy plan cycles, otherwise the customer will be included in the future energy plan cycle.
(m)  Notwithstanding the requirements of this Section, as part of a proceeding to approve a multi-year plan under subsections (f) and (g) of this Section if the  multi-year plan has been designed to maximize savings, but does not meet the cost cap limitations of this Section, the Commission shall reduce the amount of energy efficiency measures implemented for any single year, and whose costs are recovered under subsection (d) of this Section, by an amount necessary to limit the estimated average net increase due to the cost of the measures to no more than
(1) 3.5% for each of the 4 years beginning January 1,     2018,
(2) (blank),
(3)  4%  for each of the 4 years beginning January 1,     2022,
(4) 4.25% for the 4 years beginning January 1, 2026,     and
(5) 4.25% plus an increase sufficient to account for     the rate of inflation between January 1, 2026 and January 1 of the first year of each subsequent 4-year plan cycle, of the average amount paid per kilowatthour by residential eligible retail customers during calendar year 2015. An electric utility may plan to spend up to 10% more in any year during an applicable multi-year plan period to cost-effectively achieve additional savings so long as the average over the applicable multi-year plan period does not exceed the percentages defined in items (1) through (5).  To determine the total amount that may be spent by an electric utility in any single year, the applicable percentage of the average amount paid per kilowatthour shall be multiplied by the total amount of energy delivered by such electric utility in the calendar year 2015, adjusted to reflect the proportion of the utility's load attributable to customers that have opted out of subsections (a) through (j) of this Section under subsection (l) of this Section.  For purposes of this subsection (m), the amount paid per kilowatthour includes,
without limitation, estimated amounts paid for supply,
transmission, distribution, surcharges, and add-on taxes. For purposes of this Section, "eligible retail customers" shall have the meaning set forth in Section 16-111.5 of this Act.   Once the Commission has approved a plan under subsections (f) and (g) of this Section, no subsequent rate impact determinations shall be made.
(n) A utility shall take advantage of the efficiencies available through existing Illinois Home Weatherization Assistance Program infrastructure and services, such as enrollment, marketing, quality assurance and implementation, which can reduce the need for similar services at a lower cost than utility-only programs, subject to capacity constraints at community action agencies, for both  single-family and multifamily weatherization services, to the extent Illinois Home Weatherization Assistance Program community action agencies provide multifamily services.  A utility's plan shall demonstrate that in formulating annual weatherization budgets, it has sought input and coordination with community action agencies regarding agencies' capacity to expand and maximize Illinois Home Weatherization Assistance Program delivery using the ratepayer dollars collected under this Section.
(Source: P.A. 102-662, eff. 9-15-21; 103-154, eff. 6-30-23.)
(220 ILCS 5/8-104)
Sec. 8-104. Natural gas energy efficiency programs.
(a) It is the policy of the State that natural gas utilities and the Department of Commerce and Economic Opportunity are required to use cost-effective energy efficiency to reduce direct and indirect costs to consumers.  It serves the public interest to allow natural gas utilities to recover costs for reasonably and prudently incurred expenses for  cost-effective energy efficiency measures.
(b) For purposes of this Section, "energy efficiency" means measures that reduce the amount of energy required to achieve a given end use. "Energy efficiency" also includes measures that reduce the total Btus of electricity and natural gas needed to meet the end use or uses. "Cost-effective" means that the measures satisfy the total resource cost test which, for purposes of this Section, means a standard that is met if, for an investment in energy efficiency, the benefit-cost ratio is greater than one. The benefit-cost ratio is the ratio of the net present value of the total benefits of the measures to the net present value of the total costs as calculated over the lifetime of the measures.  The total resource cost test compares the sum of avoided natural gas utility costs, representing the benefits that accrue to the system and the participant in the delivery of those efficiency measures, as well as other quantifiable societal benefits, including avoided electric utility costs, to the sum of all incremental costs of end use measures (including both utility and participant contributions), plus costs to administer, deliver, and evaluate each demand-side measure, to quantify the net savings obtained by substituting demand-side measures for supply resources.  In calculating avoided costs, reasonable estimates shall be included for financial costs likely to be imposed by future regulation of emissions of greenhouse gases. The low-income programs described in item (4) of subsection (f) of this Section shall not be required to meet the total resource cost test.
(c) Natural gas utilities shall implement cost-effective energy efficiency measures to meet at least the following natural gas savings requirements, which shall be based upon the total amount of gas delivered to retail customers, other than the customers described in subsection (m) of this Section, during calendar year 2009 multiplied by the applicable percentage.  Natural gas utilities may comply with this Section by meeting the annual incremental savings goal in the applicable year or by showing that total cumulative annual savings within a multi-year planning period associated with measures implemented after May 31, 2011 were equal to the sum of each annual incremental savings requirement from the first day of the multi-year planning period through the last day of the multi-year planning period:
(1) 0.2% by May 31, 2012;
(2) an additional 0.4% by May 31, 2013, increasing     total savings to .6%;
(3) an additional 0.6% by May 31, 2014, increasing     total savings to 1.2%;
(4) an additional 0.8% by May 31, 2015, increasing     total savings to 2.0%;
(5) an additional 1% by May 31, 2016, increasing     total savings to 3.0%;
(6) an additional 1.2% by May 31, 2017, increasing     total savings to 4.2%;
(7) an additional 1.4% in the year commencing January     1, 2018;
(8) an additional 1.5% in the year commencing January     1, 2019; and
(9) an additional 1.5% in each 12-month period     thereafter.
(d) Notwithstanding the requirements of subsection (c) of this Section, a natural gas utility shall limit the amount of energy efficiency implemented in any multi-year reporting period established by subsection (f) of Section 8-104 of this Act, by an amount necessary to limit the estimated average increase in the amounts paid by retail customers in connection with natural gas service to no more than 2% in the applicable multi-year reporting period. The energy savings requirements in subsection (c) of this Section may be reduced by the Commission for the subject plan, if the utility demonstrates by substantial evidence that it is highly unlikely that the requirements could be achieved without exceeding the applicable spending limits in any multi-year reporting period. No later than September 1, 2013, the Commission shall review the limitation on the amount of energy efficiency measures implemented pursuant to this Section and report to the General Assembly, in the report required by subsection (k) of this Section, its findings as to whether that limitation unduly constrains the procurement of energy efficiency measures.
(e) The provisions of this subsection (e) apply to those multi-year plans that commence prior to January 1, 2018.  The utility shall utilize 75% of the available funding associated with energy efficiency programs approved by the Commission, and may outsource various aspects of program development and implementation.  The remaining 25% of available funding shall be used by the Department of Commerce and Economic Opportunity to implement energy efficiency measures that achieve no less than 20% of the requirements of subsection (c) of this Section. Such measures shall be designed in conjunction with the utility and approved by the Commission. The Department may outsource development and implementation of energy efficiency measures. A minimum of 10% of the entire portfolio of cost-effective energy efficiency measures shall be procured from local government, municipal corporations, school districts, and community college districts.  Five percent of the entire portfolio of cost-effective energy efficiency measures may be granted to local government and municipal corporations for market transformation initiatives. The Department shall coordinate the implementation of these measures and shall integrate delivery of natural gas efficiency programs with electric efficiency programs delivered pursuant to Section 8-103 of this Act, unless the Department can show that integration is not feasible.
The apportionment of the dollars to cover the costs to implement the Department's share of the portfolio of energy efficiency measures shall be made to the Department once the Department has executed rebate agreements, grants, or contracts for energy efficiency measures and provided supporting documentation for those rebate agreements, grants, and contracts to the utility. The Department is authorized to adopt any rules necessary and prescribe procedures in order to ensure compliance by applicants in carrying out the purposes of rebate agreements for energy efficiency measures implemented by the Department made under this Section.
The details of the measures implemented by the Department shall be submitted by the Department to the Commission in connection with the utility's filing regarding the energy efficiency measures that the utility implements.
The portfolio of measures, administered by both the utilities and the Department, shall, in combination, be designed to achieve the annual energy savings requirements set forth in subsection (c) of this Section, as modified by subsection (d) of this Section.
The utility and the Department shall agree upon a reasonable portfolio of measures and determine the measurable corresponding percentage of the savings goals associated with measures implemented by the Department.
No utility shall be assessed a penalty under subsection (f) of this Section for failure to make a timely filing if that failure is the result of a lack of agreement with the Department with respect to the allocation of responsibilities or related costs or target assignments. In that case, the Department and the utility shall file their respective plans with the Commission and the Commission shall determine an appropriate division of measures and programs that meets the requirements of this Section.
(e-5) The provisions of this subsection (e-5) shall be applicable to those multi-year plans that commence after December 31, 2017.  Natural gas utilities shall be responsible for overseeing the design, development, and filing of their efficiency plans with the Commission and may outsource development and implementation of energy efficiency measures. A minimum of 10% of the entire portfolio of cost-effective energy efficiency measures shall be procured from local government, municipal corporations, school districts, and community college districts.  Five percent of the entire portfolio of cost-effective energy efficiency measures may be granted to local government and municipal corporations for market transformation initiatives.
The utilities shall also present a portfolio of energy efficiency measures proportionate to the share of total annual utility revenues in Illinois from households at or below 150% of the poverty level.  Such programs shall be targeted to households with incomes at or below 80% of area median income.
(e-10) A utility providing approved energy efficiency measures in this State shall be permitted to recover costs of those measures through an automatic adjustment clause tariff filed with and approved by the Commission. The tariff shall be established outside the context of a general rate case and shall be applicable to the utility's customers other than the customers described in subsection (m) of this Section. Each year the Commission shall initiate a review to reconcile any amounts collected with the actual costs and to determine the required adjustment to the annual tariff factor to match annual expenditures.
(e-15)  For those multi-year plans that commence prior to January 1, 2018, each utility shall include, in its recovery of costs, the costs estimated for both the utility's and the Department's implementation of energy efficiency measures. Costs collected by the utility for measures implemented by the Department shall be submitted to the Department pursuant to Section 605-323 of the Civil Administrative Code of Illinois, shall be deposited into the Energy Efficiency Portfolio Standards Fund, and  shall be used by the Department solely for the purpose of implementing these measures. A utility shall not be required to advance any moneys to the Department but only to forward such funds as it has collected. The Department shall report to the Commission on an annual basis regarding the costs actually incurred by the Department in the implementation of the measures. Any changes to the costs of energy efficiency measures as a result of plan modifications shall be appropriately reflected in amounts recovered by the utility and turned over to the Department.
(f) No later than October 1, 2010, each gas utility shall file an energy efficiency plan with the Commission to meet the energy efficiency standards through May 31, 2014. No later than October 1, 2013, each gas utility shall file an energy efficiency plan with the Commission to meet the energy efficiency standards through May 31, 2017.  Beginning in 2017 and every 4 years thereafter, each utility shall file an energy efficiency plan with the Commission to meet the energy efficiency standards for the next applicable 4-year period beginning January 1 of the year following the filing. For those multi-year plans commencing on January 1, 2018, each utility shall file its proposed energy efficiency plan no later than 30 days after the effective date of this amendatory Act of the 99th General Assembly or May 1, 2017, whichever is later.  Beginning in 2021 and every 4 years thereafter, each utility shall file its energy efficiency plan no later than March 1. If a utility does not file such a plan on or before the applicable filing deadline for the plan, then it shall face a penalty of $100,000 per day until the plan is filed.
Each utility's plan shall set forth the utility's proposals to meet the utility's portion of the energy efficiency standards identified in subsection (c) of this Section, as modified by subsection (d) of this Section, taking into account the unique circumstances of the utility's service territory. For those plans commencing after December 31, 2021, the Commission shall seek public comment on the utility's plan and shall issue an order approving or disapproving each plan within 6 months after its submission. For those plans commencing on January 1, 2018, the Commission shall seek public comment on the utility's plan and shall issue an order approving or disapproving each plan no later than August 31, 2017, or 105 days after the effective date of this amendatory Act of the 99th General Assembly, whichever is later. If the Commission disapproves a plan, the Commission shall, within 30 days, describe in detail the reasons for the disapproval and describe a path by which the utility may file a revised draft of the plan to address the Commission's concerns satisfactorily. If the utility does not refile with the Commission within 60 days after the disapproval, the utility shall be subject to penalties at a rate of $100,000 per day until the plan is filed. This process shall continue, and penalties shall accrue, until the utility has successfully filed a portfolio of energy efficiency measures. Penalties shall be deposited into the Energy Efficiency Trust Fund and the cost of any such penalties may not be recovered from ratepayers. In submitting proposed energy efficiency plans and funding levels to meet the savings goals adopted by this Act the utility shall:
(1) Demonstrate that its proposed energy efficiency     measures will achieve the requirements that are identified in subsection (c) of this Section, as modified by subsection (d) of this Section.
(2) Present specific proposals to implement new     building and appliance standards that have been placed into effect.
(3) Present estimates of the total amount paid for     gas service expressed on a per therm basis associated with the proposed portfolio of measures designed to meet the requirements that are identified in subsection (c) of this Section, as modified by subsection (d) of this Section.
(4) For those multi-year plans that commence prior to     January 1, 2018, coordinate with the Department to present a portfolio of energy efficiency measures proportionate to the share of total annual utility revenues in Illinois from households at or below 150% of the poverty level.  Such programs shall be targeted to households with incomes at or below 80% of area median income.
(5) Demonstrate that its overall portfolio of energy     efficiency measures, not including low-income programs described in item (4) of this subsection (f) and subsection (e-5) of this Section, are cost-effective using the total resource cost test and represent a diverse cross section of opportunities for customers of all rate classes to participate in the programs.
(6) Demonstrate that a gas utility affiliated with an     electric utility that is required to comply with Section 8-103 or 8-103B of this Act has integrated gas and electric efficiency measures into a single program that reduces program or participant costs and appropriately allocates costs to gas and electric  ratepayers.  For those multi-year plans that commence prior to January 1, 2018, the Department shall integrate all gas and electric programs it delivers in any such utilities' service territories, unless the Department can show that integration is not feasible or appropriate.
(7) Include a proposed cost recovery tariff mechanism     to fund the proposed energy efficiency measures and to ensure the recovery of the prudently and reasonably incurred costs of Commission-approved programs.
(8) Provide for quarterly status reports tracking     implementation of and expenditures for the utility's portfolio of measures and, if applicable, the Department's portfolio of measures, an annual  independent review, and a full independent evaluation of the multi-year results of the performance and the cost-effectiveness of the utility's and, if applicable, Department's portfolios of measures and broader net program impacts and, to the extent practical, for adjustment of the measures on a going forward basis as a result of the evaluations. The resources dedicated to evaluation shall not exceed 3% of portfolio resources in any given multi-year period.
(g) No more than 3% of expenditures on energy efficiency measures may be allocated for demonstration of breakthrough equipment and devices.
(h) Illinois natural gas utilities that are affiliated by virtue of a common parent company may, at the utilities' request, be considered a single natural gas utility for purposes of complying with this Section.
(i) If, after 3 years, a gas utility fails to meet the efficiency standard specified in subsection (c) of this Section as modified by subsection (d), then it shall make a contribution to the Low-Income Home Energy Assistance Program.  The total liability for failure to meet the goal shall be assessed as follows:
(1) a large gas utility shall pay $600,000;
(2) a medium gas utility shall pay $400,000; and
(3) a small gas utility shall pay $200,000.
For purposes of this Section, (i) a "large gas utility" is a gas utility that on December 31, 2008, served more than 1,500,000 gas customers in Illinois; (ii) a "medium gas utility" is a gas utility that on December 31, 2008, served fewer than 1,500,000, but more than 500,000 gas customers in Illinois; and (iii) a "small gas utility" is a gas utility that on December 31, 2008, served fewer than 500,000 and more than 100,000 gas customers in Illinois. The costs of this contribution may not be recovered from ratepayers.
If a gas utility fails to meet the efficiency standard specified in subsection (c) of this Section, as modified by subsection (d) of this Section, in any 2 consecutive multi-year planning periods, then the responsibility for implementing the utility's energy efficiency measures shall be transferred to an independent program administrator selected by the Commission.  Reasonable and prudent costs incurred by the independent program administrator to meet the efficiency standard specified in subsection (c) of this Section, as modified by subsection (d) of this Section, may be recovered from the customers of the affected gas utilities, other than customers described in subsection (m) of this Section.  The utility shall provide the independent program administrator with all information and assistance necessary to perform the program administrator's duties including but not limited to customer, account, and energy usage data, and shall allow the program administrator to include inserts in customer bills.  The utility may recover reasonable costs associated with any such assistance.
(j) No utility shall be deemed to have failed to meet the energy efficiency standards to the extent any such failure is due to a failure of the Department.
(k) Not later than January 1, 2012, the Commission shall develop and solicit public comment on a plan to foster statewide coordination and consistency between statutorily mandated natural gas and electric energy efficiency programs to reduce program or participant costs or to improve program performance.  Not later than September 1, 2013, the Commission shall issue a report to the General Assembly containing its findings and recommendations.
(l) This Section does not apply to a gas utility that on January 1, 2009, provided gas service to fewer than 100,000 customers in Illinois.
(m) Subsections (a) through (k) of this Section do not apply to customers of a natural gas utility that have a North American Industry Classification System code number that is 22111 or any such code number beginning with the digits 31, 32, or 33  and (i) annual usage in the aggregate of 4 million therms or more within  the service territory of the affected gas utility or with aggregate usage of 8 million therms or more in this State and complying with the provisions of item (l) of this subsection (m); or (ii) using natural gas as feedstock and meeting the usage requirements described in item (i) of this subsection (m), to the extent such annual feedstock usage is greater than 60% of the customer's total annual usage of natural gas.
(1)  Customers described in this subsection (m) of     this Section shall apply, on a form approved on or before October 1, 2009 by the Department, to the Department to be designated as a self-directing customer ("SDC") or as an exempt customer using natural gas as a feedstock from which other products are made, including, but not limited to, feedstock for a hydrogen plant, on or before the 1st day of  February, 2010. Thereafter, application may be made not less than 6 months before the filing date of the gas utility energy efficiency plan described in subsection (f) of this Section; however, a new customer that commences taking service from a natural gas utility after February 1, 2010 may apply to become a  SDC or exempt customer up to 30 days after beginning service.  Customers described in this subsection (m) that have not already been approved by the Department may apply to be designated a self-directing customer or exempt customer, on a form approved by the Department, between September 1, 2013 and September 30, 2013.  Customer applications that are approved by the Department under this amendatory Act of the 98th General Assembly shall be considered to be a self-directing customer or exempt customer, as applicable, for the current 3-year planning period effective December 1, 2013. Such  application shall contain the following:
(A)  the customer's certification that, at the         time of its application, it qualifies to be a SDC or exempt customer described in this subsection (m) of this Section;
(B) in the case of a SDC, the customer's         certification that it has established or will establish by the beginning of the utility's multi-year planning period commencing subsequent to the application, and will maintain for accounting purposes, an energy efficiency reserve account and that the customer will accrue funds in said account to be held for the purpose of funding, in whole or in part, energy efficiency measures of the customer's choosing, which may include, but are  not limited to, projects involving combined heat and power systems that use the same energy source both for the generation of electrical or mechanical power and the production of steam or another form of useful thermal energy or the use of combustible gas produced from biomass, or both;
(C)  in the case of a SDC, the customer's         certification that annual funding levels for the energy efficiency reserve account will be equal to 2% of the customer's cost of natural gas, composed of the customer's commodity cost and the delivery service charges paid to the gas utility, or $150,000, whichever is less;
(D) in the case of a SDC, the customer's         certification that the required reserve account balance will be capped at 3 years' worth of accruals and that the customer may, at its option,  make  further deposits to the account to the extent such deposit would increase the reserve account balance above the designated cap level;
(E)  in the case of a SDC, the customer's         certification that by October 1 of each year, beginning no sooner than October 1, 2012, the customer will report to the Department information, for the 12-month period ending May 31 of the same year, on all deposits and reductions, if any, to the reserve account during the reporting year, and to the extent deposits to the reserve account in any year are in an amount less than $150,000, the basis for such reduced deposits; reserve account balances by month; a  description of energy efficiency measures  undertaken by the customer and paid for in whole or in part with funds from the reserve account; an estimate of the energy saved, or to be saved, by the measure; and that the report shall include a verification by an officer or plant manager of the customer or by a registered professional engineer or certified energy efficiency trade professional that the funds withdrawn from the reserve account were used for the energy efficiency measures;
(F)  in the case of an exempt customer, the         customer's certification of the level of gas usage as feedstock in the customer's operation in a typical year and that it will provide information establishing this level, upon request of the Department;
(G)  in the case of either an exempt customer or         a SDC, the customer's certification that it has provided the gas utility or utilities serving the customer with a copy of the application as filed with the Department;
(H) in the case of either an exempt customer or a         SDC, certification of the natural gas utility or utilities serving the customer in Illinois including the natural gas utility accounts that are the subject of the application; and
(I) in the case of either an exempt customer or a         SDC, a verification signed by a plant manager or an authorized corporate officer attesting to the truthfulness and accuracy of the information contained in the application.
(2)  The Department shall review the application to     determine that it contains the information described in provisions (A) through (I)  of item (1) of this subsection (m), as applicable. The review shall be completed within 30 days after the date the application is filed with the Department. Absent a determination by the Department within the 30-day period, the applicant shall be considered to be a SDC or exempt customer, as applicable, for all subsequent multi-year planning periods, as of the date of filing the application described in this subsection (m).  If the Department determines that the application does not contain the applicable information described in provisions (A) through (I) of item (1) of this subsection (m), it shall notify the customer, in writing, of its determination that the application does not contain the required information and identify the information that is missing, and the customer shall provide the missing information within 15 working days after the date of receipt of the Department's notification.
(3)  The Department shall have the right to audit the     information provided in the customer's application and annual reports to ensure continued compliance with the requirements of this subsection. Based on the audit, if the Department determines the customer is no longer in compliance with the requirements of items (A) through (I) of item (1) of this subsection (m), as applicable, the Department shall notify the customer in writing of the noncompliance. The customer shall have 30 days to establish its compliance, and failing to do so, may have its status as a SDC or exempt customer revoked by the Department.  The Department shall treat all information provided by any customer seeking SDC status or exemption from the provisions of this Section as strictly confidential.
(4)  Upon request, or on its own motion, the     Commission may open an investigation, no more than once every 3 years and not before October 1, 2014, to evaluate the effectiveness of the self-directing program described in this subsection (m).
Customers described in this subsection (m) that applied to the Department on January 3, 2013, were approved by the Department on February 13, 2013 to be a self-directing customer or exempt customer, and receive natural gas from a utility that provides gas service to at least 500,000 retail customers in Illinois and electric service to at least 1,000,000 retail customers in Illinois shall be considered to be a self-directing customer or exempt customer, as applicable, for the current 3-year planning period effective December 1, 2013.
(n)  The applicability of this Section to customers described in subsection (m) of this Section is conditioned on the existence of the SDC program. In no event will any provision of this Section apply to such customers after January 1, 2020.
(o)  Utilities' 3-year energy efficiency plans approved by the Commission on or before the effective date of this amendatory Act of the 99th General Assembly for the period June 1, 2014 through May 31, 2017 shall continue to be in force and effect through December 31, 2017 so that the energy efficiency programs set forth in those plans continue to be offered during the period June 1, 2017 through December 31, 2017.  Each utility is authorized to increase, on a pro rata basis, the energy savings goals and budgets approved in its plan to reflect the additional 7 months of the plan's operation.
(Source: P.A. 98-90, eff. 7-15-13; 98-225, eff. 8-9-13; 98-604, eff. 12-17-13; 99-906, eff. 6-1-17.)
(220 ILCS 5/8-105)
Sec. 8-105. (Repealed).
(Source: P.A. 96-33, eff. 7-10-09. Repealed internally, eff. 12-31-11.)
(220 ILCS 5/8-201) (from Ch. 111 2/3, par. 8-201)
Sec. 8-201. 
		
		It is the policy of this State that no person should be
denied essential utility service during the winter months due to financial
inability to pay.  It is also the policy of this State that public
utilities and residential heating customers deal with each other in good
faith and fair manner.
(Source: P.A. 84-617.)
(220 ILCS 5/8-201.4)
Sec. 8-201.4. Prohibition on use of utility name or logo by non-utility entity.  No non-utility individual, business, or entity shall use a public utility name or logo, in whole or in part, in any manner to market, solicit, sell, or bill for a home insurance, maintenance, or warranty product.  This prohibition does not apply to activities permitted to implement a program or plan approved by the Commission pursuant to an order entered under this Act. This prohibition does not apply to the partial use by a non-utility entity of a logo belonging to an electric utility that serves fewer than 200,000 customers in this State.
(Source: P.A. 102-928, eff. 1-1-23; 103-154, eff. 6-30-23.)
(220 ILCS 5/8-201.5)
Sec. 8-201.5. Military personnel in military service; no stoppage of gas or electricity; arrearage.
(a) In this Section:
"Military service" means any full-time training or duty, no matter how described under federal or State law, for which a service member is ordered to report by the President, Governor of a state, commonwealth, or territory of the United States, or other appropriate military authority.
"Service member" means a resident of Illinois who is a member of any component of the U.S. Armed Forces or the National Guard of any state, the District of Columbia, a commonwealth, or a territory of the United States.
(b) No company or electric cooperative shall for nonpayment stop gas or electricity from entering the residential premises that was the primary residence of a service member immediately before the service member was assigned to military service.
(c) In order to be eligible for the benefits granted to service members under this Section, a service member must provide the company or electric cooperative with a copy of the orders calling the service member to military service in excess of 29 consecutive days and of any orders further extending the service member's period of service.
(d) Upon the return from military service of a residential consumer who is a service member, the company or electric cooperative shall offer the residential consumer a period equal to at least the period of military service to pay any arrearages incurred during the period of the residential consumer's military service. The company or electric cooperative shall inform the residential consumer that, if the period that the company or electric cooperative offers presents a hardship to the consumer, the consumer may request a longer period to pay the arrearages and, in the case of a company that is a public utility, may request the assistance of the Illinois Commerce Commission to obtain a longer period. No late payment fees or interest shall be charged to the residential consumer during the period of military service or the repayment period.
(e) A public utility shall be permitted to recover the uncollectible costs it incurs in
complying with the requirements of this Section, including through the utility's automatic
adjustment clause tariff authorized under either Section 16-111.8 or Section 19-145 of
this Act. In the event that a public utility does not have such a tariff in effect, then the
public utility shall recover such costs consistent with the rules established by the Illinois
Commerce Commission pursuant to subparagraph (3) of subsection (f) of this Section.
(f) The Illinois Commerce Commission shall initiate a rulemaking proceeding to
establish rules regarding, at a minimum:
(1)     what documents or proof the service member     must provide to the public utility to establish that the residential premises was the primary residence of the service member immediately before the service member entered military service;
(2)     what constitutes "hardship to the consumer"     as that term is used in subsection (d) of this Section; and
(3)     the mechanism or mechanisms pursuant to which     a public utility that does not have in effect an automatic adjustment clause tariff under either Section 16-111.8 or Section 19-145 of this Act shall recover the uncollectible costs it incurs in complying with the requirements of this Section.
(g) In order to be eligible for the benefits granted to a service member under this Section, a service member who receives utility services from a not-for-profit cooperative must provide the cooperative with documentation that his or her military service materially affects his or her ability to pay for the services when payment is due.
(h) A violation of this Section constitutes a civil rights violation under the Illinois Human Rights Act.
All proceeds from the collection of any civil penalty imposed under this subsection shall be deposited into the Illinois Military Family Relief Fund.
(Source: P.A. 97-913, eff. 1-1-13.)
(220 ILCS 5/8-201.6)
Sec. 8-201.6. Deferral of deposit; victims of domestic violence. For the purposes of this Section, "domestic violence" means abuse by a family or household member, as "abuse" and "family or household members" are defined in Section 103 of the Illinois Domestic Violence Act of 1986.
A utility shall defer the utility's initial credit and deposit requirements for a period of 60 days for a residential customer or applicant who is a victim of domestic violence. To be eligible for the deferral under this Section, the domestic violence must (1) have been the basis for the issuance of an order of protection or (2) be certified by treating medical personnel, law enforcement personnel, a State's Attorney, the Attorney General, or a domestic violence shelter. The certification letter must be printed on the certifying entity's letterhead or accompanied by a letter on the certifying entity's letterhead that identifies the certifying individual.
(Source: P.A. 99-420, eff. 1-1-16.)
(220 ILCS 5/8-201.7)
Sec. 8-201.7. Prohibition on deposits for low-income residential customers or applicants.
(a) On and after the effective date of this amendatory Act of the 102nd General Assembly, no electric or gas utility shall, as a condition for standard service, require a low-income residential customer or applicant to provide a deposit as security against potential non-payment for service except when the utility has proof that the customer engaged in tampering of the electric or gas utility equipment during the previous 5 years.     Within 60 days after the effective date of this amendatory Act of the 102nd General Assembly, such utility shall refund all deposits collected from low-income customers as security against potential nonpayment for standard service to such residential customers except when the utility has proof that the customer benefited from tampering. Proof that the customer for whom the deposit is being required engaged in tampering shall be the burden of the utility and the utility shall provide the customer the opportunity to contest the finding that the customer engaged in tampering.
(b) As used in this Section:
"Low-income residential customer or applicant" means: (i) a member of a household at or below 80% of the latest median household income as reported by the United States Census Bureau for the most applicable community or county; (ii) a member of a household at or below 150% of the federal poverty level; (iii) a person who is eligible for the Illinois Low Income Home Energy Assistance Program (LIHEAP) as defined in the Energy Assistance Act; (iv) a person who is eligible to participate in the Percentage of Income Payment Plan (PIPP or PIP Plan) as defined in the Energy Assistance Act; or (v) a person who is eligible to receive Lifeline service as defined in the Universal Service Telephone Service Protection Law of 1985.
"Tampering" means any unauthorized alteration of electric or gas utility equipment or facilities by which a benefit is achieved for which the utility is not compensated, including customer self-restoration of utility service.
(Source: P.A. 102-662, eff. 9-15-21.)
(220 ILCS 5/8-201.8)
Sec. 8-201.8. Prohibition on late payment fees for low-income residential customers or applicants.
(a) Notwithstanding any other provision of this Act, as of the effective date of this amendatory Act of the 102nd General Assembly, an electric utility shall not charge a low-income residential customer or applicant a fee, charge, or penalty for late payment of any utility bill or invoice. Notwithstanding any other provision of this Act, as of January 1, 2023, a natural gas utility shall not charge a low-income residential customer or applicant a fee, charge, or penalty for late payment of any utility bill or invoice.
(b) As used in this Section, "low-income residential customer or applicant" means: (i) a member of a household at or below 80% of the latest median household income as reported by the United States Census Bureau for the most applicable community or county; (ii) a member of a household at or below 150% of the federal poverty level; (iii) a person who is eligible for the Illinois Low Income Home Energy Assistance Program (LIHEAP) as defined in the Energy Assistance Act; (iv) a person who is eligible to participate in the Percentage of Income Payment Plan (PIPP or PIP Plan) as defined in the Energy Assistance Act; or (v) a person who is eligible to receive Lifeline service as defined in the Universal Service Telephone Service Protection Law of 1985.
(Source: P.A. 102-662, eff. 9-15-21.)
(220 ILCS 5/8-201.9)
Sec. 8-201.9. Prohibition on credit card convenience fees.
(a) No electric or natural gas utility shall assess any convenience fee, surcharge, or other fee to any customer who elects to pay for service using a credit card that the electric or natural gas utility would not assess to the customer if the customer paid by other available methods acceptable to the utility. The Commission may consider as an operating expense, for the purpose of determining whether a rate or other charge or classification is sufficient, costs incurred by a utility to process payments described in this Section so long as those costs are determined to be prudent, just, and reasonable.
(b) As used in this Section, "credit card" means an instrument or device, whether known as a credit card, bank card, charge card, debit card, automated teller machine card, secured credit card, smart card, electronic purse, prepaid card, affinity card, or by any other name, issued with or without fee by an issuer for the use of the holder to obtain credit, money, goods, services, or anything else of value.
(Source: P.A. 102-662, eff. 9-15-21.)
(220 ILCS 5/8-201.10)
Sec. 8-201.10. Disconnection and credit and collections reporting.
(a) The Commission shall require all gas, electric, water and sewer public utilities under its authority to submit an annual report by May 1, 2022 and every May 1 thereafter, reporting and making publicly available in  executable, electronic spreadsheet format, by zip code, on the number of disconnections for nonpayment and reconnections that occurred in the immediately preceding calendar year, as identified in subsection (b).
(b) Each such public utility shall report to the Commission by the 15th day of each month and make publicly available in executable, electronic spreadsheet format the following information, by zip code, for the immediately preceding month:
(1) the number of customers, by customer class and     type of utility service provided, during each month;
(2) the number of customers, by customer class and     type of utility service, receiving disconnection notices during each month;
(3) the number of customers, by customer class and     type of utility service, disconnected for nonpayment during each month;
(4) the number of customers, by customer class and     type of utility service, reconnected because they have paid in full or set up payment arrangements during each month;
(5) the number of new deferred payment agreements, by     customer class and type of utility service, each month;
(6) the number of customers, by customer class and     type of utility service, taking service at the beginning of the month under existing deferred payment arrangements;
(7) the number of customers, by customer class and     type of utility service, completing deferred payment arrangements during the month;
(8) the number of payment agreements, by customer     class and type of utility service, that failed during each month;
(9) the number of customers, by customer class and     type of utility service, renegotiating deferred payment arrangements during the month;
(10) the number of customers, by customer class and     type of utility service, assessed late payment fees or charges during the month;
(11) the number of customers, by customer class and     type of utility service, taking service at the beginning of the month under existing medical payment arrangements;
(12) the number of customers, by utility service,     completing medical payment arrangements during the month;
(13) the number of customers, by utility service,     enrolling in new medical payment arrangements during the month;
(14) the number of customers, by utility service,     renegotiating medical payment arrangements plans during the month;
(15) the number of customers, by customer class and     utility service, with required deposits with the company at the beginning of the month;
(16) the number of customers, by customer class and     utility service, required to submit new deposits or increased deposits during the month;
(17) the number of customers, by customer class and     utility service, whose required deposits were reduced in part or forgone during the month;
(18) the number of customers, by customer class and     utility service, whose deposits were returned in full during the month;
(19) the number of customers, by customer class and     utility service, with past due amounts greater than 30 days past due at the beginning of the month and taking service at the beginning of the month under existing deferred payment arrangements;
(20) the dollar volume of past due accounts, by     customer class and utility service, for customers with past due amounts greater than 30 days past due at the beginning of the month and taking service at the beginning of the month under existing deferred payment arrangements;
(21) the number of customers, by customer class and     utility service, with past due amounts greater than 30 days past due at the beginning of the month and not taking service at the beginning of the month under existing deferred payment arrangements; and
(22) the dollar volume of past due accounts, by     customer class and utility service, for customers with past due amounts greater than 30 days past due at the beginning of the month and not taking service at the beginning of the month under existing deferred payment arrangements.
(c) The Commission may specify the executable, electronic spreadsheet format that utilities must adhere to when submitting the information required by this Section.  Notwithstanding the requirements of this Section, the Commission may establish an online reporting system and require each public utility to report using the online reporting system instead of filing information in executable, electronic spreadsheet format. The Commission shall make each monthly report submitted by each public utility publicly available on its website within 30 days of receipt.
(Source: P.A. 102-662, eff. 9-15-21.)
(220 ILCS 5/8-202) (from Ch. 111 2/3, par. 8-202)
Sec. 8-202. 
		
		Any public utility, or two or more public utilities, which
furnishes electricity or gas for space heating shall, during the calendar
months of November, December, January, February, and March:
(a) give written notice of its intention to terminate or cut off such
service or supply for any reason, other than by request of the customer,
to the customer.  Such notice shall be sent by U.S. Mail at least 8 days
prior to termination of service or supply or delivered by other means to
the customer 5 days prior to such termination; and
(b) deliver written notice of intention to terminate or cut off such service
or supply for any reason, other than by request of the customer, to the
Director of the local department of public health or, if there is no local
department of public health, then to the township supervisor or, if there
is no township supervisor, then to the county sheriff where the premises
receiving such service or supply is located; and
(c) send, by certified mail, prior written notice of its intention to
terminate or cut off such service or supply for any reason, other than by
request of the customer, to the owner of record and/or the mortgagee of
the premises receiving such service or supply, should the owner of record
or mortgagee make request to the public utility for any such notice.
The notice required by paragraphs (b) and (c) of this Section shall be
delivered or mailed at least 24 hours and not more than 48 hours prior to
the termination of service or supply.
Any termination notice delivered or mailed to a customer shall include a
statement advising said customer that the township supervisor, local department
of public health, or county sheriff, and the owner and/or the mortgagee,
if applicable, will be notified of the termination action at least 24 hours
prior to the termination of service or supply.
Nothing in this Act shall be construed to limit the power of the Commission
to adopt other rules and regulations pursuant to service termination notices.
No public official to whom notice is given pursuant to subparagraph (b)
of this Section shall be liable for death, injury or damages resulting from
cut-off of electricity or gas service or supply.
(Source: P.A. 84-617.)
(220 ILCS 5/8-203) (from Ch. 111 2/3, par. 8-203)
Sec. 8-203. 
		
		No public utility company which furnishes gas or
electricity for space heating shall, during the calendar months of
October, November, December, January, February and March, terminate or
cut off service to any residence or other building at the request of a
customer unless:
(a) the customer making the request identifies himself or herself as
the owner of the residence or other building or provides reasonable
assurance that the owner or the agent thereof has been notified of the
request; or
(b) the public utility company has made a reasonable effort to
ascertain the owner or the agent thereof and to notify such owner or
agent of the request; or
(c) more than 24 hours has elapsed from the time the request was
received by the public utility company.
(Source: P.A. 84-617.)
(220 ILCS 5/8-204) (from Ch. 111 2/3, par. 8-204)
Sec. 8-204. 
		
		Every public utility company which furnishes electricity to
residential customers shall (a) maintain a registry of those individuals
who are dependent on an electrically operated respirator, dialysis machine
or any other electrically operated life-support equipment, and (b)
identify with a special tag each meter used in conjunction with the
provision of electric service to such individuals.  The existence
of the registry shall be reasonably publicized by the public utility to
its residential customers and the general public.  It shall be the
responsibility, however, of any individual relying on any life-support
equipment to notify the public utility providing electrical service of his
or her dependency on such life-support equipment.
(Source: P.A. 86-1424.)
(220 ILCS 5/8-205) (from Ch. 111 2/3, par. 8-205)
Sec. 8-205. (a) Termination of gas and electric utility service to all
residential users, including all tenants of mastermetered apartment
buildings, for nonpayment of bills, where gas or electricity is used as the
only source of space heating or to control or operate the only space
heating equipment at the residence is prohibited,
(1)  on any day when the National Weather Service     forecast for the following 24 hours covering the area of the utility in which the residence is located includes a forecast that the temperature will be 32 degrees Fahrenheit or below; or
(2)  on any day preceding a holiday or a weekend when     such a forecast indicated that the temperature will be 32 degrees Fahrenheit or below during the holiday or weekend.
(b) If gas or electricity is used as the only source of space cooling or to control or operate the only space cooling equipment at a residence, then a utility may not terminate gas or electric utility service to a residential user, including all tenants of mastermetered apartment buildings, for nonpayment of bills:
(1) on any day when the National Weather Service     forecast for the following 24 hours covering the area of the utility in which the residence is located includes a forecast that the temperature will be 90 degrees Fahrenheit or above;
(2) on any day preceding a holiday or weekend when     the National Weather Service for the following 24 hours covering the area of the utility in which the residence is located includes a forecast that the temperature will be 90 degrees Fahrenheit or above during the holiday or weekend; or
(3) when the National Weather Service issues an     excessive heat watch, heat advisory, or excessive heat warning covering the area of the utility in which the residence is located.
(Source: P.A. 103-19, eff. 1-1-24.)
(220 ILCS 5/8-206) (from Ch. 111 2/3, par. 8-206)
Sec. 8-206. Winter termination for nonpayment.
(a) Notwithstanding any other provision of this Act, no
electric or gas public utility shall disconnect service to any residential
customer or mastermetered apartment building for nonpayment of a bill or
deposit where gas or electricity is used as the primary source of space
heating or is used to control or operate the primary source of space heating
equipment at the premises during the period of time from December 1 through
and including March 31 of the immediately succeeding calendar year, unless:
(1) The utility (i) has offered the customer a     deferred payment arrangement allowing for payment of past due amounts over a period of not less than 4 months not to extend beyond the following November and the option to enter into a levelized payment plan for the payment of future bills.  The maximum down payment requirements shall not exceed 10% of the amount past due and owing at the time of entering into the agreement; and (ii) has provided the customer with the names, addresses and telephone numbers of governmental and private agencies which may provide assistance to customers of public utilities in paying their utility bills; the utility shall obtain the approval of an agency before placing the name of that agency on any list which will be used to provide such information to customers;
(2) The customer has refused or failed to enter into     a deferred payment arrangement as described in paragraph (1) of this subsection (a); and
(3) All notice requirements as provided by law and     rules or regulations of the Commission have been met.
(b) Prior to termination of service for any residential customer or
mastermetered apartment building during the period from December 1 through
and including March 31 of the immediately succeeding calendar year, all
electric and gas public utilities shall, in addition to all other notices:
(1) Notify the customer or an adult residing at the     customer's premises by telephone, a personal visit to the customer's premises or by first class mail, informing the customer that:
(i) the customer's account is in arrears and the         customer's service is subject to termination for nonpayment of a bill;
(ii) the customer can avoid disconnection of         service by entering into a deferred payment agreement to pay past due amounts over a period not to extend beyond the following November and the customer has the option to enter into a levelized payment plan for the payment of future bills;
(iii) the customer may apply for any available         assistance to aid in the payment of utility bills from any governmental or private agencies from the list of such agencies provided to the customer by the utility.
Provided, however, that a public utility shall be     required to make only one such contact with the customer during any such period from December 1 through and including March 31 of the immediately succeeding calendar year.
(2) Each public utility shall maintain records which     shall include, but not necessarily be limited to, the manner by which the customer was notified and the time, date and manner by which any prior but unsuccessful attempts to contact were made.  These records shall also describe the terms of the deferred payment arrangements offered to the customer and those entered into by the utility and customers.  These records shall indicate the total amount past due, the down payment, the amount remaining to be paid and the number of months allowed to pay the outstanding balance.  No public utility shall be required to retain records pertaining to unsuccessful attempts to contact or deferred payment arrangements rejected by the customer after such customer has entered into a deferred payment arrangement with such utility.
(c) No public utility shall disconnect service for nonpayment of a bill
until the lapse of 6 business days after making the notification required by
paragraph (1) of subsection (b) so as to allow the customer an opportunity to:
(1) Enter into a deferred payment arrangement and the     option to enter into a levelized payment plan for the payment of future bills.
(2) Contact a governmental or private agency that may     provide assistance to customers for the payment of public utility bills.
(d) Any residential customer who enters into a deferred payment arrangement
pursuant to this Act, and subsequently during that period of time set forth
in subsection (a) becomes subject to termination, shall be given notice
as required by law and any rule or regulation of the Commission prior to
termination of service.
(e) During that time period set forth in subsection (a), a utility shall
not require a down payment for a deposit from a residential customer in
excess of 20% of the total deposit requested.  An additional 4 months shall
be allowed to pay the remainder of the deposit.  This provision shall not
apply to mastermetered apartment buildings or other nonresidential customers.
(f) During that period of time set forth in subsection (a), no utility
may refuse to offer a deferred payment agreement to a residential customer
who has defaulted on such an agreement within the past 12 months.  However,
no utility shall be required to enter into more than one deferred payment
arrangement under this Section with any residential customer or
mastermetered apartment building during the period from December 1 through
and including March 31 of the immediately succeeding calendar year.
(g) In order to enable customers to take advantage of energy assistance
programs, customers who can demonstrate that their applications for a local,
state or federal energy assistance program have been approved may request
that the amount they will be entitled to receive as a regular energy assistance
payment be deducted and set aside from the amount past due on which they
make deferred payment arrangements.  Payment on the set-aside amount shall
be credited when the energy assistance voucher or check is received, according
to the utility's common business practice.
(h) In no event shall any utility send a final notice to any customer
who has entered into a current deferred payment agreement and has not defaulted
on that deferred payment agreement, unless the final notice pertains to
a deposit request.
(i) Each utility shall include with each disconnection notice sent during
the period for December 1 through and including March 31 of the immediately
succeeding calendar year to a residential customer an insert explaining the
above provisions and providing a telephone number of the utility company
which the consumer may call to receive further information.
(j) Each utility shall file with the Commission prior to December 1 of
each year a plan detailing the implementation of this Section.  This plan
shall contain, but not be limited to:
(1) a description of the methods to be used to notify     residential customers as required in this Section, including the forms of written and oral notices which shall be required to include all the information contained in subsection (b) of this Section.
(2) a listing of the names, addresses and telephone     numbers of governmental and private agencies which may provide assistance to residential customers in paying their utility bills.
(3) the program of employee education and information     which shall be used by the company in the implementation of this Section.
(4) a description of methods to be utilized to inform     residential customers of those governmental and private agencies and current and planned methods of cooperation with those agencies to identify the customers who qualify for assistance in paying their utility bills.
A utility which has a plan on file with the Commission need not resubmit
a new plan each year.  However, any alteration of the plan on file must
be submitted and approved prior to December 1 of any year.
All plans are subject to review and approval by the Commission. The
Commission may direct a utility to alter its plan to comply with the
requirements of this Section.
(k) Notwithstanding any other provision of this Act, no
electric or gas public utility shall disconnect service to any residential
customer who is a participant under Section 6 of the Energy
Assistance Act for nonpayment of a bill or
deposit where gas or electricity is used as the primary source of space
heating or is used to control or operate the primary source of space heating
equipment at the premises during the period of time from December 1 through
and including March 31 of the immediately succeeding calendar year.
(l) Notwithstanding any other provision of this Act, no
electric or gas public  utility shall disconnect service to any residential customer who has notified the utility that he or she is a service member or veteran for nonpayment of a bill or deposit where gas or electricity is used as the primary source of space heating or is used to control or operate the primary source of space heating equipment at the premises during the period of time from December 1 through and
including March 31 of the immediately succeeding calendar year.
(Source: P.A. 97-77, eff. 1-1-12.)
(220 ILCS 5/8-207) (from Ch. 111 2/3, par. 8-207)
Sec. 8-207. 
		
		Any former residential customer whose gas or electric
service was used to provide or control the primary source of space heating
in the dwelling and whose service is disconnected for nonpayment of a bill or
a deposit from December 1 of the prior winter's heating season through April
1 of the current heating season shall be eligible for reconnection and a
deferred payment arrangement under the provisions of this Section, subject
to the following limitations:
A utility shall not be required to reconnect service to, and enter
into a deferred payment arrangement with, a former customer under the
provisions of this Section (1) except between November 1 and April 1 of the
current heating season for former customers who do not have applications
pending for the program described in Section 6 of the Energy Assistance Act, and except between October 1 and April 1 of the current heating
season for all former customers who do have applications pending for the
program described in Section 6 of the Energy Assistance Act and who
provide proof of application to the utility, (2) in 2 consecutive years,
(3) unless that former customer has paid at least 33 1/3% of the amount
billed for utility service rendered by that utility subsequent to December
1 of the prior year, or (4) in any instance where the utility can show
there has been tampering with the utility's wires, pipes, meters (including
locking devices), or other service equipment and further shows that the
former customer enjoyed the benefit of utility service obtained in the
aforesaid manner.
The terms and conditions of any deferred payment arrangements established
by the utility and a former customer shall take into consideration the
following factors, based upon information available from current utility
records or provided by the former customer:
(1) the amount past due;
(2) the former customer's ability to pay;
(3) the former customer's payment history;
(4) the reasons for the accumulation of the past due     amounts; and
(5) any other relevant factors relating to the former     customer's circumstances.
After the former customer's eligibility has been established in accordance
with the first paragraph of this Section and, upon the establishment of
a deferred payment agreement, the former customer shall pay 1/3 of the amount
past due (including reconnecting charge, if any) and 1/3 of any deposit
required by the utility.
Upon the payment of 1/3 of the amount past due and 1/3 of any deposit
required by the utility, the former customer's service shall be reconnected
as soon as possible.  The company and the former customer shall agree to a
payment schedule for the remaining balances which will reasonably allow the
former customer to make the payments on the remainder of the deposit and
the past due balance while paying current bills during the winter heating
season. However, the utility is not obliged to make payment arrangements
extending beyond the following November.  The utility shall allow the
former customer a minimum of 4 months in which to retire the past due
balance and 3 months in which to pay the remainder of the deposit.  The
former customer shall also be informed that payment on the amounts past due
and the deposit, if any, plus the current bills must be paid by the due
date or the customer may face termination of service pursuant to this
Section and Section 8-206.
The Commission shall develop rules to govern the reconnection of a former
customer who demonstrates a financial inability to meet the requirement of
1/3 of the amount past due and 1/3 of any deposit requested by the utility.
 The Commission's rules shall establish a means by which the former
customer's utility service may be reconnected through the payment of a
reasonable amount and upon entering  into a deferred payment agreement.
Any payment agreement made shall be in writing, with a copy provided to
the former customer.  The renegotiation and reinstatement of a customer
and the establishment of a budget payment plan shall be pursuant to rules
established by the Commission.
Not later than September 15 of each year, every gas and electric utility
shall conduct a survey of all former residential customers whose gas or
electric service was used to provide or control the primary source of space
heating in the dwelling and whose gas or electric service was terminated for
nonpayment of a bill or deposit from December 1 of the previous year to
September 15 of that year and where service at that premises has not been
restored. Not later than October 1 of each year the utility shall notify
each of these former customers that the gas or electric service will be
restored by the company for the coming heating season if the former
customer contacts the utility and makes arrangements with the utility
for reconnection of service under the conditions set forth in
this Section. A utility shall notify the former customer or an adult
member of the household by personal visit, telephone contact or mailing of
a letter by first class mail to the last known address of that former
customer.  The utility shall keep records which would indicate the date,
form and the results of such contact.
Each gas and electric utility which has former customers affected by this
Section shall file reports with the Commission providing such information
as the Commission may deem appropriate. The Commission shall notify each
gas and electric utility prior to August 1 of each year concerning the
information which is to be included in the report for that year.
In no event shall any actions taken by a utility in compliance with this
Section be deemed to abrogate or in any way interfere with the utility's
rights to pursue the normal collection processes otherwise available to it.
The Commission shall promulgate rules to implement this Section.
(Source: P.A. 92-690, eff. 7-18-02.)
(220 ILCS 5/8-208)
Sec. 8-208. 
		
		(a) The General Assembly finds that the availability of
adequate, affordable housing bears a close relationship to efficient and
reliable delivery of utility services and that the lack of affordable housing
exacerbates difficulties in the delivery of electric services.  It is further
found that the meeting of electric public utility service obligations imposed
under this Act can be attained by allocating certain resources to alleviating
housing needs.  It is declared to be the public policy of this State that
prudent investments in or contributions to projects that foster the
availability of adequate, affordable housing furthers the goals and objectives
of this Act.
(b) Beginning in calendar year 1994 and continuing through calendar year
2014, a public utility providing electric service to more than 1,000,000
customers in this State shall contribute, from retained earnings, each year
$500,000 to the Illinois Affordable Housing Trust Fund created by the Illinois
Affordable Housing Act.
(Source: P.A. 88-83; 88-653, eff. 1-1-95.)
(220 ILCS 5/8-209)
Sec. 8-209. Utility credit reporting. If a public utility reports a customer to a credit reporting agency for non-payment of an outstanding utility bill, then a public utility shall notify the credit reporting agency within 5 business days of any full payment made with certified funds or cash. For the purposes of this amendatory Act of the 97th General Assembly, certified funds means instruments that are guaranteed by the issuing institution or have cleared the issuing institution.
(Source: P.A. 97-821, eff. 1-1-13.)
(220 ILCS 5/8-218)
Sec. 8-218. Utility-scale pilot projects.
(a) Electric utilities serving greater than 500,000 customers but less than 3,000,000 customers may propose, plan for, construct, install, control, own, manage, or operate up to 2 pilot projects consisting of utility-scale photovoltaic energy generation facilities. A pilot project may consist of photovoltaic energy generation facilities located on one or more sites and may be installed or constructed in phases. Energy storage facilities that are planned for, constructed, installed, controlled, owned, managed, or operated may be constructed in connection with the photovoltaic electricity generation pilot projects.
(b) Pilot projects shall be sited in equity investment eligible communities in or near the towns of Peoria and East St. Louis and must result in economic benefits for the members of the communities in which the project will be located. The amount paid per pilot project with or without energy storage facilities cannot exceed $20,000,000. The electric utility's costs of planning for, constructing, installing, controlling, owning, managing, or operating the photovoltaic electricity generation facilities and energy storage facilities may be recovered, on a kilowatt hour basis, via an automatic adjustment clause tariff applicable to all retail customers, with the tariff to be approved by the Commission after opportunity for review, and with an annual reconciliation component; and for purposes of cost recovery, the photovoltaic electricity production facilities may be treated as regulatory assets, using the same ratemaking treatment in paragraph (1) of subsection (h) of Section 16-107.6 of this Act, provided: (1) the Commission shall have the authority to determine the reasonableness of the costs of the facilities, and (2) any monetary value of power and energy from the facilities shall be credited against the delivery services revenue requirement.
(c) Any electric utility seeking to propose, plan for, construct, install, control, own, manage, or operate a pilot project pursuant to this Section must commit to using a diverse and equitable workforce and a diverse set of contractors, including minority-owned businesses, disadvantaged businesses, trade unions, graduates of any workforce training programs established by this amendatory Act of the 102nd General Assembly, and small businesses. An electric utility must comply with the equity commitment requirements in subsection (c-10) of Section 1-75 of the Illinois Power Agency Act. The electric utility must certify that not less than the prevailing wage will be paid to employees engaged in construction activities associated with the pilot project. The electric utility must file a project labor agreement, as defined in the Illinois Power Agency Act, with the Commission prior to constructing, installing, controlling, or owning a pilot project authorized by this Section.
(Source: P.A. 102-662, eff. 9-15-21; 102-1031, eff. 5-27-22.)
(220 ILCS 5/8-301) (from Ch. 111 2/3, par. 8-301)
Sec. 8-301. 
		
		The Commission shall have power to ascertain, determine and fix
for each kind of public utility suitable and convenient standard commercial
units of service, product or commodity, which units shall be lawful units
for the purposes of this Act; to ascertain, determine and fix adequate and
serviceable standards for the measurements of quantity, quality, pressure,
initial voltage or other condition pertaining to the performing of its
service or to the furnishing of its product or commodity by any public
utility, and to prescribe reasonable regulations for examining, measuring
and testing such service, product or commodity, and to establish reasonable
rules, regulations, specifications and standards to secure the accuracy of
all meters and appliances for examining, measuring or testing such service,
product or commodity.  The Commission may purchase such materials, apparatus
and standard measuring instruments as it deems necessary to carry out the
provisions of this Section.
The Commission shall provide for the inspection of the manner in which
every public utility conforms to the reasonable regulations prescribed by
the Commission for examining, measuring and testing its service, product or
commodity, and the Commission may supplement such inspections by examining,
measuring and testing the service, product or commodity of any public utility.
Any consumer or user may have tested any appliance
for examining, measuring or testing any such service, product or commodity
upon payment of the fees fixed by the Commission.  The Commission shall
declare and establish reasonable fees to be paid for examining and testing
such appliances on the request of consumers or users, the fee to be paid by the
consumer or user at the time of his request, but to be repaid to the consumer
or user by the public utility if the measuring appliance be found unreasonably
 defective or incorrect to the disadvantage of the consumer or user.
The Commission, its officers, agents, experts or inspectors and
employees shall have power to enter upon any premises occupied by any
public utility for the purpose of making the examinations and tests
provided in the Act, and set up and use on such premises, any apparatus and
appliances and occupy reasonable space therefor.
All fees collected by the Commission under this Section shall be paid
promptly after the receipt of the same, accompanied by a detailed statement
of the same, into the Public Utility Fund in the State treasury.
(Source: P.A. 84-617.)
(220 ILCS 5/8-302) (from Ch. 111 2/3, par. 8-302)
Sec. 8-302. 
		
		The Commission shall require that every public utility
furnishing natural or artificial gas, electricity or water to the public,
where the individual consumption is measured by meter, shall, upon written
request of any consumer, cause the meter reader at the time of reading such
consumer's meter to leave at such meter a card showing the present reading
of the meter, the last previous reading, and the dates of such two readings.
(Source: P.A. 84-617.)
(220 ILCS 5/8-303) (from Ch. 111 2/3, par. 8-303)
Sec. 8-303. 
		
		Where, within 30 days of receipt of a utility bill, a
customer alleges that the level of consumption reflected in his utility
bill is unreasonably high, it shall be the responsibility of the public
utility furnishing natural or artificial gas, electricity or water to that
customer to investigate the allegation. If as a result of such an
investigation, the public utility determines that the customer's line has
been tapped, the utility shall attempt to ascertain the identity of the
third party benefiting from the usage of the utility service or for
payment for all or part of the disputed charges.  If the utility determines
that the landlord of the building or his agent is the party who benefited
from the usage of the utility service, either the utility or the customer
may petition the court for the appointment of receiver to collect the rents
due and to remit a portion to the utility company for payment of bills for
the tapped service, for current bills and for any expenses incurred by the
utility as a result of the tap.  The receiver shall make all reasonable
efforts, including the obtaining of court orders, to provide to the utility
access to the building.  Any changes in the building's piping which are
necessitated by the tap shall be at the expense of the person benefiting
from the tap.
If the utility determines that the landlord of the building is not the
party who benefited from the usage of the utility service, the customer
shall be so notified and shall also be informed by the utility of a right
to register a dispute pursuant to procedures developed by the Commission
for resolution of disputed bills, including his right to bring a complaint
before the Commission if an agreement with the utility cannot be reached.
In order to enable the customer to ascertain whether the level
of consumption is greater than the amounts billed in
other billing periods and to eliminate to the fullest extent
practicable consecutive estimated bills, the public utility shall make an
actual meter reading at least every second billing
period. If a meter reader is unable to gain access to the meter for the
purpose of making an actual reading, the public utility shall take other
appropriate and reasonable measures to read the meter.
Nothing in this Section shall preclude either the customer or the public
utility from filing a complaint with the State's Attorney located in the
county where the utility service is being rendered to allege an unlawful
theft of the customer's utility service.
(Source: P.A. 84-617.)
(220 ILCS 5/8-304)
Sec. 8-304. (Repealed).
(Source: P.A. 84-617. Repealed by P.A. 100-840, eff. 8-13-18.)
(220 ILCS 5/8-305)
Sec. 8-305. 
		Braille billing statements. 
		Upon the request of a customer, a
public utility that serves at least 50,000 customers shall furnish billing
statements in braille.
(Source: P.A. 88-497.)
(220 ILCS 5/8-306)
Sec. 8-306. Special provisions relating to water and sewer utilities.
(a)  No later than 120 days after the effective date of this amendatory Act of the 94th General Assembly, the Commission shall prepare, make available to customers upon request, and post on its Internet web site information concerning the service obligations of water and sewer utilities and remedies that a customer may pursue for a violation of the customer's rights. The information shall specifically address the rights of a customer of a water or sewer utility in the following situations:
(1)  The customer's water meter is replaced.
(2)  The customer's bill increases by more than 50%     within one billing period.
(3)  The customer's water service is terminated.
(4)  The customer wishes to complain after receiving     a termination of service notice.
(5)  The customer is unable to make payment on a     billing statement.
(6)  A rate is filed, including without limitation a     surcharge or annual reconciliation filing, that will increase the amount billed to the customer.
(7)  The customer is billed for services provided     prior to the date covered by the billing statement.
(8)  The customer is due to receive a credit.
Each billing statement issued by a water or sewer utility shall include an Internet web site address where the customer can view the information required under this subsection (a) and a telephone number that the customer may call to request a copy of the information.
(b)  A water or sewer utility may discontinue service only after it has mailed or delivered by other means a written notice of discontinuance substantially in the form of Appendix A of 83 Ill. Adm. Code 280. The notice must include the Internet web site address where the customer can view the information required under subsection (a) and a telephone number that the customer may call to request a copy of the information. Any notice required to be delivered or mailed to a customer prior to discontinuance of service shall be delivered or mailed separately from any bill. Service shall not be discontinued until at least 5 days after delivery or 8 days after the mailing of this notice. Service shall not be discontinued and shall be restored if discontinued for the reason which is the subject of a dispute or complaint during the pendency of informal or formal complaint procedures of the Illinois Commerce Commission under 83 Ill. Adm. Code 280.160 or 280.170, where the customer has complied with those rules. Service shall not be discontinued and shall be restored if discontinued where a customer has established a deferred payment agreement pursuant to 83 Ill. Adm. Code 280.110 and has not defaulted on such agreement. Residential customers who are indebted to a utility for past due utility service shall have the opportunity to make arrangements with the utility to retire the debt by periodic payments, referred to as a deferred payment agreement, unless this customer has failed to make payment under such a plan during the past 12 months. The terms and conditions of a reasonable deferred payment agreement shall be determined by the utility after consideration of the following factors, based upon information available from current utility records or provided by the customer or applicant:
(1)               size of the past due account;
(2)         customer or applicant's ability to pay;
(3)         customer or applicant's payment history;
(4)         reason for the outstanding indebtedness;     and
(5)         any other relevant factors relating to     the circumstances of the customer or applicant's service.
							A residential customer shall pay a maximum of one-fourth of the amount past due and owing at the time of entering into the deferred payment agreement, and the water or sewer utility shall allow a minimum of 2 months from the date of the agreement and a maximum of 12 months for payment to be made under a deferred payment agreement. Late payment charges may be assessed against the amount owing that is the subject of a deferred payment agreement.
(c)  A water or sewer utility shall provide notice as required by subsection (a) of Section 9-201 after the filing of each information sheet under a purchased water surcharge, purchased sewage treatment surcharge, or qualifying infrastructure plant surcharge. The utility also shall post notice of the filing in accordance with the requirements of 83 Ill. Adm. Code 255. Unless filed as part of a general rate increase, notice of the filing of a purchased water surcharge rider, purchased sewage treatment surcharge rider, or qualifying infrastructure plant surcharge rider also shall be given in the manner required by this subsection (c) for the filing of information sheets.
(d)  Commission rules pertaining to formal and informal complaints against public utilities shall apply with full and equal force to water and sewer utilities and their customers, including provisions of 83 Ill. Adm. Code 280.170, and the Commission shall respond to each complaint by providing the consumer with a copy of the utility's response to the complaint and a copy of the Commission's review of the complaint and its findings. The Commission shall also provide the consumer with all available options for recourse.
(e)  Any refund shown on the billing statement of a customer of a water or sewer utility must be itemized and must state if the refund is an adjustment or credit.
(f)  Water service for building construction purposes. At the request of any municipality or township within the service area of a public utility that provides water service to customers within the municipality or township, a public utility must (1) require all water service used for building construction purposes to be measured by meter and subject to approved rates and charges for metered water service and (2) prohibit the unauthorized use of water taken from hydrants or service lines installed at construction sites.
(g)  Water meters.
(1) Periodic testing. Unless otherwise approved by     the Commission, each service water meter shall be periodically inspected and tested in accordance with the schedule specified in 83 Ill. Adm. Code 600.340, or more frequently as the results may warrant, to insure that the meter accuracy is maintained within the limits set out in 83 Ill. Adm. Code 600.310.
(2)  Meter tests requested by customer.
(A)  Each utility furnishing metered water         service shall, without charge, test the accuracy of any meter upon request by the customer served by such meter, provided that the meter in question has not been tested by the utility or by the Commission within 2 years previous to such request.  The customer or his or her representatives shall have the privilege of witnessing the test at the option of the customer.  A written report, giving the results of the test, shall be made to the customer.
(B)  When a meter that has been in service less         than 2 years since its last test is found to be accurate within the limits specified in 83 Ill. Adm. Code 600.310, the customer shall pay a fee to the utility not to exceed the amounts specified in 83 Ill. Adm. Code 600.350(b).  Fees for testing meters not included in this Section or so located that the cost will be out of proportion to the fee specified will be determined by the Commission upon receipt of a complete description of the case.
(3)  Commission referee tests.  Upon written     application to the Commission by any customer, a test will be made of the customer's meter by a representative of the Commission. For such a test, a fee as provided for in subsection (g)(2) shall accompany the application. If the meter is found to be registering more than 1.5%  fast on the average when tested as prescribed in 83 Ill. Adm. Code 600.310, the utility shall refund to the customer the amount of the fee. The utility shall in no way disturb the meter after a customer has made an application for a referee test until authority to do so is given by the Commission or the customer in writing.
(h) Water and sewer utilities; low usage. Each public utility that provides water and sewer service must establish a unit sewer rate, subject to review by the Commission, that applies only to those customers who use less than 1,000 gallons of water in any billing period.
(i)  Water and sewer utilities; separate meters. Each public utility that provides water and sewer service must offer separate rates for water and sewer service to any commercial or residential customer who uses separate meters to measure each of those services. In order for the separate rate to apply, a combination of meters must be used to measure the amount of water that reaches the sewer system and the amount of water that does not reach the sewer system.
(j)  Each water or sewer public utility must disclose on each billing statement any amount billed that is for service provided prior to the date covered by the billing statement. The disclosure must include the dates for which the prior service is being billed. Each billing statement that includes an amount billed for service provided prior to the date covered by the billing statement must disclose the dates for which that amount is billed and must include a copy of the document created under subsection (a) and a statement of current Commission rules concerning unbilled or misbilled service.
(k) When the customer is due a refund resulting from payment of an overcharge, the utility shall credit the customer in the amount of overpayment with interest from the date of overpayment by the customer.  The rate for interest shall be at the appropriate rate determined by the Commission under 83 Ill. Adm. Code 280.70.
(l)  Water and sewer public utilities; subcontractors.  The Commission shall adopt rules for water and sewer public utilities to provide notice to the customers of the proper kind of identification that a subcontractor must present to the customer, to prohibit a subcontractor from soliciting or receiving payment of any kind for any service provided by the water or sewer public utility or the subcontractor, and to establish sanctions for violations.
(m)  Water and sewer public utilities; unaccounted-for water.  By December 31, 2006, each water public utility shall file tariffs with the Commission to establish the maximum percentage of unaccounted-for water that would be considered in the determination of any rates or surcharges.  The rates or surcharges approved for a water public utility shall not include charges for unaccounted-for water in excess of this maximum percentage without well-documented support and justification for the Commission to consider in any request to recover charges in excess of the tariffed maximum percentage.
(n)  Rate increases; public forums. When any public utility providing water or sewer service proposes a general rate increase, in addition to other notice requirements, the water or sewer public utility must notify its customers of their right to request a public forum.  A customer or group of customers must make written request to the Commission for a public forum and must also provide written notification of the request to the customer's municipal or, for unincorporated areas, township government. The Commission, at its discretion, may schedule the public forum. If it is determined that public forums are required for multiple municipalities or townships, the Commission shall schedule these public forums, in locations within approximately 45 minutes drive time of the municipalities or townships for which the public forums have been scheduled. The public utility must provide advance notice of 30 days for each public forum to the governing bodies of those units of local government affected by the increase. The day of each public forum shall be selected so as to encourage the greatest public participation. Each public forum will begin at 7:00 p.m. Reports and comments made during or as a result of each public forum must be made available to the hearing officials and reviewed when drafting a recommended or tentative decision, finding or order pursuant to Section 10-111 of this Act.
(Source: P.A. 94-950, eff. 6-27-06.)
(220 ILCS 5/8-401) (from Ch. 111 2/3, par. 8-401)
Sec. 8-401. 
		
		Every public utility subject to this Act shall provide
service and facilities which are in all respects adequate, efficient,
reliable and environmentally safe and which, consistent with these
obligations, constitute the least-cost means of meeting the utility's service obligations.
(Source: P.A. 84-617.)
(220 ILCS 5/8-402) (from Ch. 111 2/3, par. 8-402)
Sec. 8-402. 
		(Repealed).
(Source: P.A. 89-445, eff. 2-7-96.  Repealed by P.A. 90-561, eff.
12-16-97.)
(220 ILCS 5/8-402.1) (from Ch. 111 2/3, par. 8-402.1)
Sec. 8-402.1. 
		(Repealed).
(Source: P.A. 87-173.  Repealed by P.A. 90-561, eff. 12-16-97.)
(220 ILCS 5/8-402.2)
Sec. 8-402.2. Public Schools Carbon-Free Assessment programs.
(a)   Within one year after the effective date of this amendatory
Act of the 102nd General Assembly, each electric utility serving over
500,000 retail customers in this State shall implement a Public
Schools Carbon-Free Assessment program.
(b)   Each utility's Public Schools Carbon-Free Assessment program
shall include the following requirements:
(1)   Each plan shall be designed to offer within the     utility's service territory to assist public schools, as defined by Section 1-3 of the School Code, to increase the efficiency of their energy usage, to reduce the carbon emissions associated with their energy usage, and to move toward a goal of public schools being carbon-free in their energy usage by 2030. The program shall include a target of completing Public Schools Carbon-Free Assessment for all public schools in the utility's service territory by December 31, 2029.
(2)   The Public Schools Carbon-Free Assessment shall     be a generally standardized assessment, but may incorporate flexibility to reflect the circumstances of individual public schools and public school districts.
(3)   The Public Schools Carbon-Free Assessment shall     include, but not be limited to, comprehensive analyses of the following subjects:
(A)     The top energy efficiency savings         opportunities for the public school, by energy saved;
(B)   The total achievable solar energy potential         on or nearby a public school's premises and able to provide power to a school;
(C)   The infrastructure required to support         electrification of the facility's space heating and water heating needs;
(D)   The infrastructure requirements to support         electrification of a school's transportation needs; and
(E)   The investments required to achieve a WELL         Certification or similar certification as determined through methods developed and updated by the International WELL Building Institute or similar or successor organizations.
(4)   The Public Schools Carbon-Free Assessment also     shall include, but not be limited to, mechanical insulation evaluation inspection and inspection of the building envelope(s).
(5)     With respect to those public school     construction projects for public schools within the service territory of a utility serving over 500,000 retail customers in this State and for which a public school district applies for a grant under Section 5-40 of the School Construction Law on or after June 1, 2023, the district must submit a copy of the applicable Public Schools Carbon-Free Assessment report, or, if no such Public Schools Carbon-Free Assessment has been performed, request the applicable utility to perform such a Public Schools Carbon-Free Assessment and submit a copy of the Public Schools Carbon-Free Assessment report promptly when it becomes available. The Public Schools Carbon-Free Assessment report shall include, but not limited to, an energy audit of both the building envelope and the building's mechanical insulation system. It shall also include an inspection of both the building envelope and the mechanical insulation system. The district must demonstrate how the construction project is designed and managed to achieve the goals that all public elementary and secondary school facilities in the State are able to be powered by clean energy by 2030, and for such facilities to achieve carbon-free energy sources for space heat, water heat, and transportation by 2050.
(6)     The results of each Public Schools     Carbon-Free Assessment shall be memorialized by the utility or by a third party acting on behalf of the utility in a non-confidential report form that includes recommendations and redacts all confidential information and shall be provided to the applicable public school. Each utility shall be required to retain a copy of each Public Schools Carbon-Free Assessment report and to provide copies of each non-confidential report to the Illinois Power Agency and the Illinois Capital Development Board within 3 months of its completion. The Illinois Power Agency shall promptly make the results of each non-confidential report available for public inspection on its website.
(7)     The Public Schools Carbon-Free Assessment     shall be conducted in coordination with each utility's energy efficiency and demand-response plans under Sections 8-103, 8-103A, and 8-103B of this Act, to the extent applicable. Nothing in this Section is intended to modify or require modification of those plans. However, the utility may request a modification of a plan approved by the Commission, and the Commission may approve the requested modification, if the modification is consistent with the provisions of this Section and Section 8-103B of this Act.
(8)   If there are no other providers of assessments     that are substantively the same as those being performed by utilities pursuant to this Section by 2024, a utility that has a Public Schools Carbon-Free Assessment program may offer assessments to public schools that are not served by a utility subject to this Section at the utility's cost.
(9)   The Public Schools Carbon-Free Assessment shall     be offered to and performed for public schools in the utility's service territory on a complimentary basis by each utility, with no Assessment fee charged to the public schools for the Assessments. Nothing in this Section is intended to prohibit the utility from recovering through rates approved by the Commission the utility's prudent and reasonable costs of complying with this Section.
(10)   Utilities shall make efforts to prioritize the     completion of Public Schools Carbon-Free Assessments for the following school districts by December 31, 2022: East St. Louis School District 189, Harvey School District 152, Thornton Township High School District 205. Utilities shall also prioritize the completion of Public Schools Carbon-Free Assessments for schools located within environmental justice communities or schools that are categorized as a Tier 1 or Tier 2 school based on the latest annual evidence-based funding distribution process by the State Board of Education.
(Source: P.A. 102-662, eff. 9-15-21; 102-1123, eff. 1-27-23.)
(220 ILCS 5/8-403) (from Ch. 111 2/3, par. 8-403)
Sec. 8-403. The Commission shall design and implement policies which
encourage the economical utilization of cogeneration and small power
production, as these terms are defined in Section 3-105, item (7) of subsection (b),
including specifically, but not limited to, the cogeneration or production
of heat, steam or electricity by municipal corporations or any other
political subdivision of this State. No public utility shall discriminate
in any way with respect to the conditions or price for provision of
maintenance power, standby power and supplementary power as these terms are
defined by current Commission rules, or for any other service. The prices
charged by a utility for
maintenance power, standby power, supplementary power and all other such
services shall be cost-based and just and reasonable.
The Commission shall conduct a study of procedures and policies to
encourage the full and economical utilization of cogeneration and small
power production including, but not limited to, (1) requiring utilities to
pay full avoided costs, including long-term avoided capacity costs to
cogenerators and small power producers and (2) requiring
utilities to make available upon request of the State or a unit of
local government, transmission and distribution services to transmit
electrical energy produced by cogeneration or small power production
facilities located in any structure or on any real property of the State or
unit of local government to other locations of this State or a unit of
local government.  The Commission shall report on this study, with
recommendation for legislative consideration, to the General Assembly by
March 1, 1986.
(Source: P.A. 95-481, eff. 8-28-07.)
(220 ILCS 5/8-403.1) (from Ch. 111 2/3, par. 8-403.1)
Sec. 8-403.1. Electricity purchased from qualified solid waste energy
facility; tax credit; distributions for economic development.
(a) It is hereby declared to be the policy of this State to encourage the
development of alternate energy production facilities in order to conserve our
energy resources and to provide for their most efficient use.
(b) For the purpose of this Section and Section 9-215.1, "qualified
solid waste energy facility" means a facility determined by the
Illinois Commerce Commission to qualify as such under the Local Solid
Waste Disposal Act, to use methane gas generated from landfills as its
primary fuel, and to possess characteristics that would enable it to qualify
as a cogeneration or small power production facility under federal law.
(c) In furtherance of the policy declared in this Section, the
Illinois Commerce Commission shall require electric utilities to enter into
long-term contracts to purchase electricity from qualified solid waste
energy facilities located in the electric utility's service area, for a
period beginning on the date that the facility begins generating
electricity and having a duration of not less than 10 years
in the case of facilities fueled by landfill-generated methane, or 20
years in the case of facilities fueled by methane generated from a landfill
owned by a forest preserve district.  The purchase rate contained in such
contracts shall be equal to the average amount per kilowatt-hour paid from
time to time by the unit or units of local government in which the
electricity generating facilities are located, excluding amounts paid for
street lighting and pumping service.
(d) Whenever a public utility is required to purchase electricity
pursuant to subsection (c) above, it shall be entitled to credits in
respect of its obligations to remit to the State taxes it has
collected under the Electricity Excise Tax Law equal to the amounts,
if any, by which payments for such electricity
exceed (i) the then current rate at which the utility must purchase the
output of qualified facilities pursuant to the federal Public
Utility Regulatory Policies Act of 1978, less (ii) any costs, expenses, losses,
damages or other amounts incurred by the utility, or for which it becomes
liable, arising out of its failure to obtain such electricity from such other
sources.  The amount of any such
credit shall, in the first instance, be
determined by the utility, which shall make a monthly report of such credits
to the Illinois Commerce Commission and, on its monthly tax return, to the
Illinois Department of Revenue. Under no circumstances shall a utility be
required to purchase electricity from a qualified solid waste energy facility
at the rate prescribed in subsection (c) of this Section if such purchase would
result in estimated tax credits that exceed, on a monthly basis, the utility's
estimated obligation to remit to the State taxes it has
collected under the Electricity Excise Tax Law. The
owner or operator shall negotiate facility operating conditions with the
purchasing utility in accordance with that utility's posted standard terms and
conditions for small power producers. If the Department of Revenue disputes the
amount of any such credit, such dispute shall be decided by the Illinois
Commerce Commission.  Whenever a qualified solid waste energy facility has paid
or otherwise
satisfied in full the capital costs or indebtedness incurred in developing
and implementing the qualified solid waste energy facility, whenever the qualified solid waste energy facility ceases to operate and produce electricity from methane gas generated from landfills, or at the end of the contract entered into pursuant to subsection (c) of this Section, whichever occurs first, the qualified solid waste energy facility shall
reimburse the Public Utility Fund and the General Revenue
Fund in the State treasury for the actual
reduction in payments to those Funds caused by this
subsection (d) in a
manner to be determined by the Illinois Commerce Commission and based on
the manner in which revenues for those Funds were reduced. The payments shall be made to the Illinois Commerce Commission, which shall determine the appropriate disbursements to the Public Utility Fund and the General Revenue Fund based on this subsection (d).
(e) The Illinois Commerce Commission shall not require an electric
utility to purchase electricity from any qualified solid waste energy facility
which is owned or operated by
an entity that is primarily engaged in the
business of producing or selling electricity, gas, or useful thermal energy
from a source other than one or more qualified solid waste energy facilities.
(e-5) A qualified solid waste energy facility may receive the purchase rate provided in subsection (c) of this Section only for kilowatt-hours generated by the use of methane
gas generated from landfills.   The purchase rate provided in subsection (c) of this Section does not apply to electricity generated by the use of a fuel that is not methane gas generated from landfills.   If the Illinois Commerce Commission determines that a qualified solid waste energy facility has violated the requirement regarding the use of methane gas generated from a landfill as set forth in this subsection (e-5), then the Commission shall issue an order requiring that the qualified solid waste energy facility repay the State for all dollar amounts of electricity sales that are determined by the Commission to be the result of the violation.    As part of that order, the Commission shall have the authority to revoke the facility's approval to act as a qualified solid waste energy facility granted by the Commission under this Section. If the amount owed by the qualified solid waste energy facility is not received by the Commission within 90 days after the date of the Commission's order that requires repayment, then the Commission shall issue an order that revokes the facility's approval to act as a qualified solid waste energy facility granted by the Commission under this Section.  The Commission's action that vacates prior qualified solid waste energy facility approval does not excuse the repayment to the State treasury required by subsection (d) of this Section for utility tax credits accumulated up to the time of the Commission's action.

A qualified solid waste energy facility must receive Commission approval before it may use any fuel in addition to methane gas generated from a landfill in order to generate electricity.    If a qualified solid waste energy facility petitions the Commission to use any fuel in addition to methane gas generated from a landfill to generate electricity, then the Commission shall have the authority to do the following:
(1) establish the methodology for determining the     amount of electricity that is generated by the use of methane gas generated from a landfill and the amount that is generated by the use of other fuel;
(2) determine all reporting requirements for the     qualified solid waste energy facility that are necessary for the Commission to determine the amount of electricity that is generated by the use of methane gas from a landfill and the amount that is generated by the use of other fuel and the resulting payments to the qualified solid waste energy facility; and
(3) require that the qualified solid waste energy     facility, at the qualified solid waste energy facility's expense, install metering equipment that the Commission determines  is necessary to enforce compliance with this subsection (e-5).
A public utility that is required to enter into a long-term purchase contract with a qualified solid waste energy facility has no duty to determine whether the electricity being purchased was generated by the use of methane gas generated from a landfill or was generated by the use of some other fuel in violation of the requirements of this subsection (e-5).
(f) This Section does not require an electric utility to construct
additional facilities unless those facilities are paid for by the owner or
operator of the affected qualified solid waste energy facility.
(g) The Illinois Commerce Commission shall require that: (1) electric
utilities use the electricity purchased from a qualified solid waste
energy facility to displace electricity generated from nuclear power or
coal mined and purchased outside the boundaries of the State of Illinois
before displacing electricity generated from coal mined and purchased
within the State of Illinois, to the extent possible, and (2) electric
utilities report annually to the Commission on the extent of such
displacements.
(h) Nothing in this Section is intended to cause an electric utility
that is required to purchase power hereunder to incur any economic loss as
a result of its purchase.  All amounts paid for power which a utility is
required to purchase pursuant to subparagraph (c) shall be deemed to be
costs prudently incurred for purposes of computing charges under rates
authorized by Section 9-220 of this Act.  Tax credits provided for herein
shall be reflected in charges made pursuant to rates so authorized to the
extent such credits are based upon a cost which is also reflected in such
charges.
(i) Beginning in February 1999 and through January 2013, each qualified
solid waste energy facility that sells electricity to an electric utility at
the purchase rate described in subsection (c) shall file with the Department
of Revenue on or before the 15th of each month a form, prescribed by the
Department of Revenue, that states the number of kilowatt hours of electricity
for which payment was received at that purchase rate from electric utilities
in Illinois during the immediately
preceding month.  This form shall be accompanied by a payment from the
qualified solid waste energy facility in an amount equal to six-tenths of a
mill ($0.0006) per kilowatt hour of electricity stated on the form.  Beginning
on the effective date of this amendatory Act of the 92nd General
Assembly, a qualified solid waste energy facility must file the form required
under this subsection (i) before the 15th of each month regardless of whether
the facility received any payment in the previous month.  Payments received by
the Department of Revenue shall be deposited into the Municipal Economic
Development Fund, a trust fund created outside the State treasury.
The State Treasurer may invest the moneys in the Fund in any investment
authorized by the Public Funds Investment Act, and investment income shall be
deposited into and become part of the Fund.  Moneys in the Fund shall be used
by the State Treasurer as provided in subsection (j).
Beginning on July 1, 2006 through January 31, 2013, each month the State Treasurer shall certify the following to the State Comptroller:
(A) the amount received by the Department of Revenue     under this subsection (i) during the immediately preceding month; and
(B) the amount received by the Department of Revenue     under this subsection (i) in the corresponding month in calendar year 2002.As soon as practicable after receiving the certification from the State Treasurer, the State Comptroller shall transfer from the General Revenue Fund to the Municipal Economic Development Fund in the State treasury an amount equal to the amount by which the amount calculated under item (B) of this paragraph exceeds the amount calculated under item (A) of this paragraph, if any.
The obligation of a
qualified solid waste energy facility to make payments into the Municipal
Economic Development Fund shall terminate upon either: (1) expiration or
termination of a facility's contract to sell electricity to an electric
utility at the purchase rate described in subsection (c); or (2) entry
of an enforceable, final, and non-appealable order by a court of competent
jurisdiction that Public Act 89-448 is invalid.  Payments by a
qualified solid waste energy facility into the Municipal Economic Development
Fund do not relieve the qualified solid waste energy facility of its
obligation to reimburse the Public Utility Fund and the General Revenue Fund
for the actual reduction in payments
to those Funds as a result of credits received by electric utilities under
subsection (d).
A qualified solid waste energy facility that fails to timely file the
requisite form and payment as required by this subsection (i) shall be subject
to penalties and interest in conformance with the provisions of the Illinois
Uniform Penalty and Interest Act.
Every qualified solid waste energy facility subject to the provisions of this
subsection (i) shall keep and maintain records and books of its sales pursuant
to subsection (c), including payments received from those sales and the
corresponding tax payments made in accordance with this subsection (i), and for
purposes of enforcement of this subsection (i) all such books and records shall
be subject to inspection by the Department of Revenue or its duly authorized
agents or employees.
When a qualified solid waste energy facility fails to file the form or make
the payment required under this subsection (i), the Department of Revenue, to
the extent that it is practical, may enforce the payment obligation in a manner
consistent with Section 5 of the Retailers' Occupation Tax Act, and if
necessary may impose and enforce a tax lien in a manner consistent with
Sections 5a, 5b, 5c, 5d, 5e, 5f,
 5g, and 5i of the Retailers' Occupation Tax Act.  No tax lien may be imposed
or enforced, however, unless a qualified solid waste energy facility fails to
make the payment required under this subsection (i).  Only to the extent
necessary and for the purpose of enforcing this subsection (i), the Department
of Revenue may secure necessary information from a qualified solid waste energy
facility in a manner consistent with Section 10 of
the Retailers' Occupation Tax Act.
All information received by the Department of Revenue in its administration
and enforcement of this subsection (i) shall be confidential in a manner
consistent with Section 11 of the Retailers' Occupation Tax Act.  The
Department of Revenue may adopt rules to implement the provisions of this
subsection (i).
For purposes of implementing the maximum aggregate distribution provisions in
subsections (j) and (k), when a qualified solid waste energy facility makes a
late payment to the Department of Revenue for deposit into the Municipal
Economic Development Fund, that payment and deposit shall be attributed to the
month and corresponding quarter in which the payment should have been made, and
the Treasurer shall make retroactive distributions or refunds, as the case may
be, whenever such late payments so require.
(j) The State Treasurer, without appropriation, must make distributions
immediately after January 15, April 15, July 15, and October 15 of each
year, up to maximum aggregate distributions of $500,000 for the distributions
made in the 4 quarters beginning with the April distribution and ending with
the January distribution,
from the Municipal Economic Development Fund to each city, village, or
incorporated town located in Cook County that has approved construction within its boundaries of an incinerator
that will burn recovered wood processed for fuel to generate electricity and will commence operation after 2009.  Total distributions in the
aggregate to all qualified cities, villages, and incorporated towns in the 4
quarters beginning with the April distribution and ending with the January
distribution shall not exceed $500,000.  The amount
of each distribution shall be determined pro rata based on the population of
the city, village, or incorporated town compared to the total population of all
cities, villages, and incorporated towns eligible to receive a distribution.
Distributions received by a city, village, or incorporated town must be held in
a separate account and may
be used only to promote and enhance industrial, commercial, residential,
service, transportation, and recreational activities and facilities within its
boundaries, thereby enhancing the employment opportunities, public health and
general welfare, and
economic development within the community, including administrative
expenditures exclusively to further these activities.  Distributions may also be used for cleanup of open dumping from vacant properties and the removal of structures condemned by the city, village, or incorporated town. These
funds, however, shall not be used by the city, village, or incorporated town,
directly or
indirectly, to purchase, lease, operate, or in any way subsidize the operation
of any incinerator, and these funds shall not be paid, directly
or indirectly, by the city, village, or incorporated town to the owner,
operator, lessee, shareholder, or bondholder of any incinerator.
Moreover, these funds shall not be used to pay attorneys fees in any litigation
relating to the validity of Public Act 89-448.  Nothing in
this Section prevents a city, village, or incorporated town from using other
corporate funds for any legitimate purpose.  For purposes of this subsection,
the term "municipal waste" has the meaning ascribed to it in Section 3.290 of the Environmental Protection Act.
(k) If maximum aggregate distributions of $500,000 under subsection (j)
have been made after the January distribution from the Municipal Economic
Development Fund, then the balance in the Fund shall be refunded to the
qualified
solid waste energy facilities that made payments that were deposited into the
Fund during the previous 12-month period.  The refunds shall be prorated based
upon the facility's payments in relation to total payments for that 12-month
period.
(l) Beginning January 1, 2000, and each January 1 thereafter, each city,
village, or incorporated town that received distributions from the Municipal
Economic Development Fund, continued to hold any of those distributions, or
made expenditures from those distributions during the immediately preceding
year shall submit to
a financial and compliance and program audit of those distributions performed
by the Auditor General at no cost to the city, village, or incorporated town
that received the distributions.  The audit should be completed by June 30 or
as soon thereafter as possible.  The audit shall be submitted to the State
Treasurer and those officers enumerated in Section 3-14 of the Illinois State
Auditing Act.
If the Auditor General finds that distributions have been expended in violation
of this Section, the Auditor General shall refer the matter to the Attorney
General.  The Attorney General may recover, in a civil action, 3 times the
amount of any distributions illegally expended.
For purposes of this subsection, the terms "financial audit," "compliance
audit", and "program audit" have the meanings ascribed to them in Sections 1-13
and 1-15 of the Illinois State Auditing Act.
(m) On and after the effective date of this amendatory Act of the 94th General Assembly, beginning on the first date on which renewable energy certificates or other saleable representations are sold by a qualified solid waste energy facility, with or without  the electricity generated by the facility, and utilized by an electric utility or another electric supplier to comply with a renewable energy portfolio standard mandated by Illinois law or mandated by order of the Illinois Commerce Commission, that qualified solid waste energy facility may not sell electricity pursuant to this Section and shall be exempt from the requirements of subsections (a) through (l) of this Section, except that it shall remain obligated for any reimbursements required under subsection (d) of this Section. All of the provisions of this Section shall remain in full force and effect with respect to any qualified solid waste energy facility that sold electric energy pursuant to this Section at any time before July 1, 2006 and that does not sell renewable energy certificates or other saleable representations to meet the requirements of a renewable energy portfolio standard mandated by Illinois law or mandated by order of the Illinois Commerce Commission.
(n) Notwithstanding any other provision of law to the contrary, beginning on July 1, 2006, the Illinois Commerce Commission shall not issue any order determining that a facility is a qualified solid waste energy facility unless the qualified solid waste energy facility was determined by the Illinois Commerce Commission to be a qualified solid waste energy facility before July 1, 2006. As a guide to the intent,

interpretation, and application of this amendatory Act of the

94th General Assembly, it is hereby declared to be the policy

of this State to honor each qualified solid waste energy facility

contract in existence on the effective date of this amendatory Act of

the 94th General Assembly if the qualified solid waste energy

facility continues to meet the requirements of this Section for

the duration of its respective contract term.
(Source: P.A. 96-449, eff. 8-14-09.)
(220 ILCS 5/8-404) (from Ch. 111 2/3, par. 8-404)
Sec. 8-404. 
		(Repealed).
(Source: P.A. 87-812.  Repealed by P.A. 90-561, eff. 12-16-97.)
(220 ILCS 5/8-405)
Sec. 8-405. (Repealed).
(Source: P.A. 84-617. Repealed by P.A. 100-840, eff. 8-13-18.)
(220 ILCS 5/8-405.1)
Sec. 8-405.1. (Repealed).
(Source: P.A. 89-445, eff. 2-7-96. Repealed by P.A. 100-840, eff. 8-13-18.)
(220 ILCS 5/8-406) (from Ch. 111 2/3, par. 8-406)
(Text of Section before amendment by P.A. 103-569)
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) After September 11, 1987 (the effective date of Public Act 85-377), no
construction shall commence on any new nuclear
power plant 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 Director of the Illinois Environmental
Protection Agency 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.
As used in this Section, "high level nuclear waste" means those aqueous
wastes resulting from the operation of the first cycle of the solvent
extraction system or equivalent and the concentrated wastes of the
subsequent extraction cycles or equivalent in a facility for reprocessing
irradiated reactor fuel and shall include spent fuel assemblies prior to
fuel reprocessing.
(d) In making its determination under subsection (b) of this Section, the Commission shall attach primary
weight to the cost or cost savings to the customers of the utility. The
Commission may consider any or all factors which will or may affect such
cost or cost savings, including the public utility's engineering judgment regarding the materials used for construction.
(e) The Commission may issue a temporary certificate which shall remain
in force not to exceed one year in cases of emergency, to assure maintenance
of adequate service or to serve particular customers, without notice or
hearing, pending the determination of an application for a certificate, and
may by regulation exempt from the requirements of this Section temporary
acts or operations for which the issuance of a certificate will not be
required in the public interest.
A public utility shall not be required to obtain but may apply for and
obtain a certificate of public convenience and necessity pursuant to this
Section with respect to any matter as to which it has received the
authorization or order of the Commission under the Electric Supplier Act,
and any such authorization or order granted a public utility by the
Commission under that Act shall as between public utilities be deemed to
be, and shall have except as provided in that Act the same force and effect
as, a certificate of public convenience and necessity issued pursuant to this
Section.
No electric cooperative shall be made or shall become a party to or shall
be entitled to be heard or to otherwise appear or participate in any
proceeding initiated under this Section for authorization of power plant
construction and as to matters as to which a remedy is available under the
Electric Supplier Act.
(f) Such certificates may be altered or modified by the Commission, upon
its own motion or upon application by the person or corporation affected.
Unless exercised within a period of 2 years from the grant thereof,
authority conferred by a certificate of convenience and necessity issued by
the Commission shall be null and void.
No certificate of public convenience and necessity shall be construed as
granting a monopoly or an exclusive privilege, immunity or franchise.
(g) A public utility that undertakes any of the actions described in items (1) through (3) of this subsection (g) or that has obtained approval pursuant to Section 8-406.1 of this Act shall not be required to comply with the requirements of this Section to the extent such requirements otherwise would apply. For purposes of this Section and Section 8-406.1 of this Act, "high voltage electric service line" means an electric line having a design voltage of 100,000 or more. For purposes of this subsection (g), a public utility may do any of the following:
(1) replace or upgrade  any existing high voltage     electric service line and related facilities, notwithstanding its length;
(2) relocate any existing high voltage electric     service line and related facilities, notwithstanding its length, to accommodate construction or expansion of a roadway or other transportation infrastructure; or
(3) construct a high voltage electric service line     and related facilities that is constructed solely to serve a single customer's premises or to provide a generator interconnection to the public utility's transmission system and that will pass under or over the premises  owned by the customer or generator to be served or under or over premises for which the customer or generator has secured the necessary right of way.
(h)  A public utility seeking to construct a high-voltage electric service line and related facilities (Project) must show that the utility has held a minimum of 2 pre-filing public meetings to receive public comment concerning the Project in each county where the Project is to be located, no earlier than 6 months prior to filing an application for a certificate of public convenience and necessity from the Commission. Notice of the public meeting shall be published in a newspaper of general circulation within the affected county once a week for 3 consecutive weeks, beginning no earlier than one month prior to the first public meeting. If the Project traverses 2 contiguous counties and where in one county the transmission line mileage and number of landowners over whose property the proposed route traverses is one-fifth or less of the transmission line mileage and number of such landowners of the other county, then the utility may combine the 2 pre-filing meetings in the county with the greater transmission line mileage and affected landowners. All other requirements regarding pre-filing meetings shall apply in both counties. Notice of the public meeting, including a description of the Project, must be provided in writing to the clerk of each county where the Project is to be located. A representative of the Commission shall be invited to each pre-filing public meeting.
(i) For applications filed after August 18, 2015 (the effective date of Public Act 99-399), the Commission shall, by certified mail, notify each owner of record of land, as identified in the records of the relevant county tax assessor, included in the right-of-way over which the utility seeks in its application to construct a high-voltage electric line of the time and place scheduled for the initial hearing on the public utility's application.  The utility shall reimburse the Commission for the cost of the postage and supplies incurred for mailing the notice.
(Source: P.A. 102-609, eff. 8-27-21; 102-662, eff. 9-15-21; 102-813, eff. 5-13-22; 102-931, eff. 5-27-22.)
(Text of Section after amendment by P.A. 103-569)
Sec. 8-406. Certificate of public convenience and necessity.
(a) No public utility not owning any city or village franchise nor engaged in performing any public service or in furnishing any product or commodity within this State as of July 1, 1921 and not possessing a certificate of public convenience and necessity from the Illinois Commerce Commission, the State Public Utilities Commission, or the Public Utilities Commission, at the time Public Act 84-617 goes into effect (January 1, 1986), shall transact any business in this State until it shall have obtained a certificate from the Commission that public convenience and necessity require the transaction of such business. A certificate of public convenience and necessity requiring the transaction of public utility business in any area of this State shall include authorization to the public utility receiving the certificate of public convenience and necessity to construct such plant, equipment, property, or facility as is provided for under the terms and conditions of its tariff and as is necessary to provide utility service and carry out the transaction of public utility business by the public utility in the designated area.
(b) No public utility shall begin the construction of any new plant, equipment, property, or facility which is not in substitution of any existing plant, equipment, property, or facility, or any extension or alteration thereof or in addition thereto, unless and until it shall have obtained from the Commission a certificate that public convenience and necessity require such construction. Whenever after a hearing the Commission determines that any new construction or the transaction of any business by a public utility will promote the public convenience and is necessary thereto, it shall have the power to issue certificates of public convenience and necessity. The Commission shall determine that proposed construction will promote the public convenience and necessity only if the utility demonstrates: (1) that the proposed construction is necessary to provide adequate, reliable, and efficient service to its customers and is the least-cost means of satisfying the service needs of its customers or that the proposed construction will promote the development of an effectively competitive electricity market that operates efficiently, is equitable to all customers, and is the least cost means of satisfying those objectives; (2) that the utility is capable of efficiently managing and supervising the construction process and has taken sufficient action to ensure adequate and efficient construction and supervision thereof; and (3) that the utility is capable of financing the proposed construction without significant adverse financial consequences for the utility or its customers.
(b-5) As used in this subsection (b-5):
"Qualifying direct current applicant" means an entity that seeks to provide direct current bulk transmission service for the purpose of transporting electric energy in interstate commerce.
"Qualifying direct current project" means a high voltage direct current electric service line that crosses at least one Illinois border, the Illinois portion of which is physically located within the region of the Midcontinent Independent System Operator, Inc., or its successor organization, and runs through the counties of Pike, Scott, Greene, Macoupin, Montgomery, Christian, Shelby, Cumberland, and Clark, is capable of transmitting electricity at voltages of 345 kilovolts or above, and may also include associated interconnected alternating current interconnection facilities in this State that are part of the proposed project and reasonably necessary to connect the project with other portions of the grid.
Notwithstanding any other provision of this Act, a qualifying direct current applicant that does not own, control, operate, or manage, within this State, any plant, equipment, or property used or to be used for the transmission of electricity at the time of its application or of the Commission's order may file an application on or before December 31, 2023 with the Commission pursuant to this Section or Section 8-406.1 for, and the Commission may grant, a certificate of public convenience and necessity to construct, operate, and maintain a qualifying direct current project. The qualifying direct current applicant may also include in the application requests for authority under Section 8-503. The Commission shall grant the application for a certificate of public convenience and necessity and requests for authority under Section 8-503 if it finds that the qualifying direct current applicant and the proposed qualifying direct current project satisfy the requirements of this subsection and otherwise satisfy the criteria of this Section or Section 8-406.1 and the criteria of Section 8-503, as applicable to the application and to the extent such criteria are not superseded by the provisions of this subsection. The Commission's order on the application for the certificate of public convenience and necessity shall also include the Commission's findings and determinations on the request or requests for authority pursuant to Section 8-503. Prior to filing its application under either this Section or Section 8-406.1, the qualifying direct current applicant shall conduct 3 public meetings in accordance with subsection (h) of this Section. If the qualifying direct current applicant demonstrates in its application that the proposed qualifying direct current project is designed to deliver electricity to a point or points on the electric transmission grid in either or both the PJM Interconnection, LLC or the Midcontinent Independent System Operator, Inc., or their respective successor organizations, the proposed qualifying direct current project shall be deemed to be, and the Commission shall find it to be, for public use. If the qualifying direct current applicant further demonstrates in its application that the proposed transmission project has a capacity of 1,000 megawatts or larger and a voltage level of 345 kilovolts or greater, the proposed transmission project shall be deemed to satisfy, and the Commission shall find that it satisfies, the criteria stated in item (1) of subsection (b) of this Section or in paragraph (1) of subsection (f) of Section 8-406.1, as applicable to the application, without the taking of additional evidence on these criteria. Prior to the transfer of functional control of any transmission assets to a regional transmission organization, a qualifying direct current applicant shall request Commission approval to join a regional transmission organization in an application filed pursuant to this subsection (b-5) or separately pursuant to Section 7-102 of this Act. The Commission may grant permission to a qualifying direct current applicant to join a regional transmission organization if it finds that the membership, and associated transfer of functional control of transmission assets, benefits Illinois customers in light of the attendant costs and is otherwise in the public interest. Nothing in this subsection (b-5) requires a qualifying direct current applicant to join a regional transmission organization. Nothing in this subsection (b-5) requires the owner or operator of a high voltage direct current transmission line that is not a qualifying direct current project to obtain a certificate of public convenience and necessity to the extent it is not otherwise required by this Section 8-406 or any other provision of this Act.
(c) As used in this subsection (c):
"Decommissioning" has the meaning given to that term in subsection (a) of Section 8-508.1.
"Nuclear power reactor" has the meaning given to that term in Section 8 of the Nuclear Safety Law of 2004.
After the effective date of this amendatory Act of the 103rd General Assembly, no construction shall commence on any new nuclear power reactor with a nameplate capacity of more than 300 megawatts of electricity to be located within this State, and no certificate of public convenience and necessity or other authorization shall be issued therefor by the Commission, until the Illinois Emergency Management Agency and Office of Homeland Security, in consultation with the Illinois Environmental Protection Agency and the Illinois Department of Natural Resources, finds that the United States Government, through its authorized agency, has identified and approved a demonstrable technology or means for the disposal of high level nuclear waste, or until such construction has been specifically approved by a statute enacted by the General Assembly. Beginning January 1, 2026, construction may commence on a new nuclear power reactor with a nameplate capacity of 300 megawatts of electricity or less within this State if the entity constructing the new nuclear power reactor has obtained all permits, licenses, permissions, or approvals governing the construction, operation, and funding of decommissioning of such nuclear power reactors required by: (1) this Act; (2) any rules adopted by the Illinois Emergency Management Agency and Office of Homeland Security under the authority of this Act; (3) any applicable federal statutes, including, but not limited to, the Atomic Energy Act of 1954, the Energy Reorganization Act of 1974, the Low-Level Radioactive Waste Policy Amendments Act of 1985, and the Energy Policy Act of 1992; (4) any regulations promulgated or enforced by the U.S. Nuclear Regulatory Commission, including, but not limited to, those codified at Title X, Parts 20, 30, 40, 50, 70, and 72 of the Code of Federal Regulations, as from time to time amended; and (5) any other federal or State statute, rule, or regulation governing the permitting, licensing, operation, or decommissioning of such nuclear power reactors. None of the rules developed by the Illinois Emergency Management Agency and Office of Homeland Security or any other State agency, board, or commission pursuant to this Act shall be construed to supersede the authority of the U.S. Nuclear Regulatory Commission. The changes made by this amendatory Act of the 103rd General Assembly shall not apply to the uprate, renewal, or subsequent renewal of any license for an existing nuclear power reactor that began operation prior to the effective date of this amendatory Act of the 103rd General Assembly.
None of the changes made in this amendatory Act of the 103rd General Assembly are intended to authorize the construction of nuclear power plants powered by nuclear power reactors that are not either: (1) small modular nuclear reactors; or (2) nuclear power reactors licensed by the U.S. Nuclear Regulatory Commission to operate in this State prior to the effective date of this amendatory Act of the 103rd General Assembly.
(d) In making its determination under subsection (b) of this Section, the Commission shall attach primary weight to the cost or cost savings to the customers of the utility. The Commission may consider any or all factors which will or may affect such cost or cost savings, including the public utility's engineering judgment regarding the materials used for construction.
(e) The Commission may issue a temporary certificate which shall remain in force not to exceed one year in cases of emergency, to assure maintenance of adequate service or to serve particular customers, without notice or hearing, pending the determination of an application for a certificate, and may by regulation exempt from the requirements of this Section temporary acts or operations for which the issuance of a certificate will not be required in the public interest.
A public utility shall not be required to obtain but may apply for and obtain a certificate of public convenience and necessity pursuant to this Section with respect to any matter as to which it has received the authorization or order of the Commission under the Electric Supplier Act, and any such authorization or order granted a public utility by the Commission under that Act shall as between public utilities be deemed to be, and shall have except as provided in that Act the same force and effect as, a certificate of public convenience and necessity issued pursuant to this Section.
No electric cooperative shall be made or shall become a party to or shall be entitled to be heard or to otherwise appear or participate in any proceeding initiated under this Section for authorization of power plant construction and as to matters as to which a remedy is available under the Electric Supplier Act.
(f) Such certificates may be altered or modified by the Commission, upon its own motion or upon application by the person or corporation affected. Unless exercised within a period of 2 years from the grant thereof, authority conferred by a certificate of convenience and necessity issued by the Commission shall be null and void.
No certificate of public convenience and necessity shall be construed as granting a monopoly or an exclusive privilege, immunity or franchise.
(g) A public utility that undertakes any of the actions described in items (1) through (3) of this subsection (g) or that has obtained approval pursuant to Section 8-406.1 of this Act shall not be required to comply with the requirements of this Section to the extent such requirements otherwise would apply. For purposes of this Section and Section 8-406.1 of this Act, "high voltage electric service line" means an electric line having a design voltage of 100,000 or more. For purposes of this subsection (g), a public utility may do any of the following:
(1) replace or upgrade any existing high voltage     electric service line and related facilities, notwithstanding its length;
(2) relocate any existing high voltage electric     service line and related facilities, notwithstanding its length, to accommodate construction or expansion of a roadway or other transportation infrastructure; or
(3) construct a high voltage electric service line     and related facilities that is constructed solely to serve a single customer's premises or to provide a generator interconnection to the public utility's transmission system and that will pass under or over the premises owned by the customer or generator to be served or under or over premises for which the customer or generator has secured the necessary right of way.
(h) A public utility seeking to construct a high-voltage electric service line and related facilities (Project) must show that the utility has held a minimum of 2 pre-filing public meetings to receive public comment concerning the Project in each county where the Project is to be located, no earlier than 6 months prior to filing an application for a certificate of public convenience and necessity from the Commission. Notice of the public meeting shall be published in a newspaper of general circulation within the affected county once a week for 3 consecutive weeks, beginning no earlier than one month prior to the first public meeting. If the Project traverses 2 contiguous counties and where in one county the transmission line mileage and number of landowners over whose property the proposed route traverses is one-fifth or less of the transmission line mileage and number of such landowners of the other county, then the utility may combine the 2 pre-filing meetings in the county with the greater transmission line mileage and affected landowners. All other requirements regarding pre-filing meetings shall apply in both counties. Notice of the public meeting, including a description of the Project, must be provided in writing to the clerk of each county where the Project is to be located. A representative of the Commission shall be invited to each pre-filing public meeting.
(i) For applications filed after August 18, 2015 (the effective date of Public Act 99-399), the Commission shall, by certified mail, notify each owner of record of land, as identified in the records of the relevant county tax assessor, included in the right-of-way over which the utility seeks in its application to construct a high-voltage electric line of the time and place scheduled for the initial hearing on the public utility's application. The utility shall reimburse the Commission for the cost of the postage and supplies incurred for mailing the notice.
(Source: P.A. 102-609, eff. 8-27-21; 102-662, eff. 9-15-21; 102-813, eff. 5-13-22; 102-931, eff. 5-27-22; 103-569, eff. 6-1-24.)
(220 ILCS 5/8-406.1)
Sec. 8-406.1. Certificate of public convenience and necessity; expedited procedure.
(a) A public utility may apply for a certificate of public convenience and necessity pursuant to this Section for the construction of any new high voltage electric service line and related facilities (Project). To facilitate the expedited review process of an application filed pursuant to this Section, an application shall include all of the following:
(1) Information in support of the application that     shall include the following:
(A)  A detailed description of the Project,         including location maps and plot plans to scale showing all major components.
(B)  The following engineering data:
(i) a detailed Project description including:
(I) name and destination of the Project;
(II) design voltage rating (kV);
(III) operating voltage rating (kV); and
(IV) normal peak operating current rating;
(ii) a conductor, structures, and substations             description including:
(I) conductor size and type;
(II) type of structures;
(III) height of typical structures;
(IV) an explanation why these structures                 were selected;
(V) dimensional drawings of the typical                 structures to be used in the Project; and
(VI) a list of the names of all new (and                 existing if applicable) substations or switching stations that will be associated with the proposed new high voltage electric service line;
(iii) the location of the site and             right-of-way including:
(I) miles of right-of-way;
(II) miles of circuit;
(III) width of the right-of-way; and
(IV) a brief description of the area                 traversed by the proposed high voltage electric service line, including a description of the general land uses in the area and the type of terrain crossed by the proposed line;
(iv) assumptions, bases, formulae, and             methods used in the development and preparation of the diagrams and accompanying data, and a technical description providing the following information:
(I) number of circuits, with                 identification as to whether the circuit is overhead or underground;
(II) the operating voltage and frequency;                 and
(III) conductor size and type and number                 of conductors per phase;
(v) if the proposed interconnection is an             overhead line, the following additional information also must be provided:
(I) the wind and ice loading design                 parameters;
(II) a full description and drawing of a                 typical supporting structure, including strength specifications;
(III) structure spacing with typical                 ruling and maximum spans;
(IV) conductor (phase) spacing; and
(V) the designed line-to-ground and                 conductor-side clearances;
(vi) if an underground or underwater             interconnection is proposed, the following additional information also must be provided:
(I) burial depth;
(II) type of cable and a description of                 any required supporting equipment, such as insulation medium pressurizing or forced cooling;
(III) cathodic protection scheme; and
(IV) type of dielectric fluid and                 safeguards used to limit potential spills in waterways;
(vii) technical diagrams that provide             clarification of any item under this item (1) should be included; and
(viii) applicant shall provide and identify a             primary right-of-way and one or more alternate rights-of-way for the Project as part of the filing. To the extent applicable, for each right-of-way, an applicant shall provide the information described in this subsection (a). Upon a showing of good cause in its filing, an applicant may be excused from providing and identifying alternate rights-of-way.
(2) An application fee of $100,000, which shall be     paid into the Public Utility Fund at the time the Chief Clerk of the Commission deems it complete and accepts the filing.
(3) Information showing that the utility has held a     minimum of 3 pre-filing public meetings to receive public comment concerning the Project in each county where the Project is to be located, no earlier than 6 months prior to the filing of the application. Notice of the public meeting shall be published in a newspaper of general circulation within the affected county once a week for 3 consecutive weeks, beginning no earlier than one month prior to the first public meeting. If the Project traverses 2 contiguous counties and where in one county the transmission line mileage and number of landowners over whose property the proposed route traverses is 1/5 or less of the transmission line mileage and number of such landowners of the other county, then the utility may combine the 3 pre-filing meetings in the county with the greater transmission line mileage and affected landowners. All other requirements regarding pre-filing meetings shall apply in both counties. Notice of the public meeting, including a description of the Project, must be provided in writing to the clerk of each county where the Project is to be located. A representative of the Commission shall be  invited to each pre-filing public meeting.
For applications filed after the effective date of this amendatory Act of the 99th General Assembly, the Commission shall, by certified mail, notify each owner of record of the land, as identified in the records of the relevant county tax assessor, included in the primary or alternate rights-of-way identified in the utility's application of the time and place scheduled for the initial hearing upon the public utility's application.  The utility shall reimburse the Commission for the cost of the postage and supplies incurred for mailing the notice.
(b) At the first status hearing the administrative law judge shall set a schedule for discovery that shall take into consideration the expedited nature of the proceeding.
(c)    Nothing in this Section prohibits a utility from requesting, or the Commission from approving, protection of confidential or proprietary information under applicable law. The public utility may seek confidential protection of any of the information provided pursuant to this Section, subject to Commission approval.
(d) The public utility shall publish notice of its application in the official State newspaper within 10 days following the date of the application's filing.
(e) The public utility shall establish a dedicated website for the Project 3 weeks prior to the first public meeting and maintain the website until construction of the Project is complete. The website address shall be included in all public notices.
(f) The Commission shall, after notice and hearing, grant a certificate of public convenience and necessity filed in accordance with the requirements of this Section if, based upon the  application filed with the Commission and the evidentiary record, it finds the Project will promote the public convenience and necessity and that all of the following criteria are satisfied:
(1) That the Project is necessary to provide     adequate, reliable, and efficient service to the public utility's customers and is the least-cost means of satisfying the service needs of the public utility's  customers or that the Project will promote the development of an effectively competitive electricity market that operates efficiently, is equitable to all customers, and is the least cost means of satisfying those objectives.
(2) That the public utility is capable of efficiently     managing and supervising the construction process and has taken sufficient action to ensure adequate and efficient construction and supervision of the construction.
(3) That the public utility is capable of financing     the proposed construction without significant adverse financial consequences for the utility or its customers.
(g) The Commission shall issue its decision with findings of fact and conclusions of law granting or denying the application no later than 150 days after the application is filed. The Commission may extend the 150-day deadline upon notice by an additional 75 days if, on or before the 30th day after the filing of the application, the Commission finds that good cause exists to extend the 150-day period.
(h) In the event the Commission grants a public utility's application for a certificate pursuant to this Section, the public utility shall pay a one-time construction fee to each county in which the Project is constructed within 30 days after the completion of construction.  The construction fee shall be $20,000 per mile of high voltage electric service line constructed in that county, or a proportionate fraction of that fee. The fee shall be in lieu of any permitting fees that otherwise would be imposed by a county.   Counties receiving a payment under this subsection (h) may distribute all or portions of the fee to local taxing districts in that county.
(i) Notwithstanding any other provisions of this Act, a decision granting a certificate under this Section shall include an order pursuant to Section 8-503 of this Act authorizing or directing the construction of the high voltage electric service line and related facilities as approved by the Commission, in the manner and within the time specified in said order.
(Source: P.A. 102-931, eff. 5-27-22.)
(220 ILCS 5/8-406.2)
Sec. 8-406.2. Certificate of public convenience and necessity; extension of utility service area and facilities to serve designated hardship areas.
(a) This Section is intended to provide a mechanism by which a gas public utility may extend its service territory and gas distribution system to provide service to designated low-income areas whose residents do not have access to natural gas service and must purchase more costly alternatives to satisfy their energy needs.
(b) In this Section:
"Designated hardship area" is limited to Pembroke Township, if the Township meets certain requirements. Any "designated hardship area" only applies to the specific community of Pembroke within the scope of the Project. Pembroke Township will only be categorized as a "designated hardship area" if it meets the following requirements:
(1) the area is designated as a qualified census     tract by the U.S. Department of Housing and Urban Development as published in the most current Federal Register; if the U.S. Department of Housing and Urban Development ceases to make this designation, then at least 25% of the households in the area are at or below the poverty level; and
(2) the area is not currently served by a gas utility.
"Hardship area facilities" means all gas distribution system facilities that are proposed to be constructed or extended and used to serve the designated hardship area, through and including retail gas meters. "Hardship area facilities" includes the capacity to address reasonably foreseeable growth in areas adjacent to or in the vicinity of the designated hardship area.
(c) A gas public utility may apply for a certificate of public convenience and necessity pursuant to this Section to increase its gas service territory and extend its gas distribution system to serve a designated hardship area. An application under this Section shall include all of the following:
(1) a description of the designated hardship area and     its relationship to the existing gas distribution system of the applicant;
(2) a showing that the designated hardship area meets     the criteria for being a designated hardship area under  subsection (b) of this Section;
(3) a description of the hardship area facilities     proposed to serve the designated hardship area;
(4) a projection of the costs to construct and deploy     the hardship area facilities;
(5) a showing that the estimated cost to construct     and deploy the hardship area facilities is equal to or less than 250% of the amount allowed under the gas utilities' then current tariffs to provide standard service to extend main and services; and
(6) a statement to confirm that the public utility     has held at least 2 pre-filing public meetings in the community and considered public input from those meetings when developing and implementing its plans.
(d) The Commission shall, after notice and hearing, grant a certificate of public convenience and necessity under this Section if, based upon the application filed with the Commission and the evidentiary record, the Commission finds that all of the following criteria are satisfied:
(1) the area to be served is a designated hardship     area;
(2) the proposed hardship area facilities will     provide adequate, reliable, and efficient gas delivery service to the customers within the designated hardship area and are the least-cost means of providing such gas delivery service to these customers;
(3) the public utility is capable of efficiently     managing and supervising the construction of the hardship area facilities and has taken sufficient action to ensure adequate and efficient construction and supervision of the construction;
(4) the public utility is capable of financing the     construction of the hardship area facilities without significant adverse financial consequences for the utility or its customers;
(5) the estimated cost to construct and deploy the     hardship area facilities is equal to or less than 250% of the amount allowed under the gas utilities then current tariffs to provide standard service to extend main and services;
(6) the public utility can guarantee that residents     of Hopkins Park who choose to opt out of converting to a natural gas delivery service will not be assessed any charges relating to the pipeline construction or any other fees relating to the designated hardship area facilities;
(7) the public utility disclosed to the Commission     the mapping of the proposed pipeline and infrastructure management requirements within the designated hardship area; and
(8) the public utility has guaranteed that, before     implementation, it will disclose to the Commission the cost to the utility for customers of Hopkins Park to utilize gas services.
(e) The Commission shall issue its decision with findings of fact and conclusions of law granting or denying the application no later than 120 days after the application is filed.
(Source: P.A. 102-609, eff. 8-27-21.)
(220 ILCS 5/8-407) (from Ch. 111 2/3, par. 8-407)
Sec. 8-407. 
		
		(a) The Commission, after granting any certificate of
public convenience and necessity for the construction of a new electric
generating facility, shall reevaluate the propriety and necessity for the
certificate at least every 3 years and shall consider in the reevaluation
any and all changes in the forecasts and circumstances relied upon in its
initial decision to grant the certificate, including but not limited to, each
criterion that is outlined in this Section as a precondition for the granting
of a certificate and any changes in the energy plans for the utility and the
State.
(b) Whenever the Commission grants any certificate of public convenience
and necessity for the construction of a new electric generating facility,
the Commission shall design and establish all procedures necessary for it to
thoroughly and effectively evaluate, supervise, and monitor construction, and
shall thereafter take all steps necessary to assure that construction is
efficient and economical.
The Commission shall have the power to conduct a construction cost audit
at any time during construction, or to arrange for such an audit to be
conducted by persons independent of the utility and selected by the
Commission, whenever the Commission has cause to believe that such audit is
necessary, or likely to be beneficial, to the efficiency or economy of
construction. The cost of such an independent audit shall be borne
initially by the utility, but shall be recovered as an expense through
normal ratemaking procedures pursuant to this Act.
(c) The Commission shall have the power to withdraw or alter any
certificate of public convenience and necessity including any certificate
granted for the construction of a new electric generating facility or a
substantial alteration or addition to an existing generating facility where it
determines that:
(i) circumstances have changed so substantially that     continued construction is no longer necessary or beneficial to ratepayers; or
(ii) the utility has failed to substantially comply     with the requirements and conditions of its certificate or subsequent Commission orders with respect to the construction process.
(Source: P.A. 87-959.)
(220 ILCS 5/8-408)
Sec. 8-408. Energy efficiency plans for small multi-jurisdictional utilities.
(a) Any electric or gas public utility with fewer than 200,000 customers in Illinois on January 1, 2007 that offers energy efficiency programs to its customers in a state adjacent to Illinois may seek the approval of the Commission to offer the same or comparable energy efficiency programs to its customers in Illinois. For each program to be offered, the utility shall submit to the Commission:
(1) a description of the program;
(2) a proposed implementation schedule and method;
(3) the number of eligible participants;
(4) the expected rate of participation per year;
(5) the estimated annual peak demand and energy     savings;
(6) the budget or level of spending; and
(7) the rate impacts and average bill impacts, by     customer class, resulting from the program.
The Commission shall approve each program demonstrated to be cost-effective. Programs for low-income customers shall be approved by the Commission even if they have not been demonstrated to be cost-effective if they are demonstrated to be reasonable. An order of the State agency that regulates the rates of the utility in the adjacent state that finds a program to be cost-effective or reasonable shall be sufficient to demonstrate that the program is cost-effective or reasonable for the utility's customers in Illinois. Approved programs may be delivered by the utility or by a contractor or agent of the utility.
(b) Notwithstanding the provisions of Section 9-201, a public utility providing approved energy efficiency programs in the State shall be permitted to recover the reasonable costs of those programs through an automatic adjustment clause tariff filed with and approved by the Commission. Each year the Commission shall initiate a review to reconcile any amounts collected with the actual costs and to determine the adjustment to the annual tariff factor to match annual expenditures. The determination shall be made within 90 days after the date of initiation of the review.
(c) The utility may request a waiver of one or more components of an approved energy efficiency program at any time in order to improve the program's effectiveness. The Commission may grant the  waiver if good cause is shown by the utility. Notwithstanding the cessation of the programs, a utility shall
file a final reconciliation of the amounts collected as compared to the actual costs and shall continue the resulting factor until any over-recovery or under-recovery approaches zero.
(d) A public utility that offers approved energy efficiency programs in the State may do so
through at least December 31, 2012. The Commission shall
monitor the performance of the energy efficiency programs and, on or before October 31,
2012, the Commission shall make a determination regarding whether
the programs should be continued beyond calendar year 2012. The     Commission shall also file a written report with the General Assembly explaining the basis for that determination and detailing the results of the energy efficiency programs,
including energy savings, participation numbers, and costs.
(Source: P.A. 95-660, eff. 1-1-08.)
(220 ILCS 5/8-501) (from Ch. 111 2/3, par. 8-501)
Sec. 8-501. 
		
		Whenever the Commission, after a hearing had upon its own motion
or upon complaint, shall find that the rules, regulations, practices,
equipment, appliances, facilities or service of any public utility, or the
methods of manufacture, distribution, transmission, storage or supply
employed by it, are unjust, unreasonable, unsafe, improper, inadequate or
insufficient, the Commission shall determine the just, reasonable, safe,
proper, adequate or sufficient rules, regulations, practices, equipment,
appliances, facilities, service or methods to be observed, furnished,
constructed, enforced or employed and it shall fix the same by its order,
decision, rule or regulation. The Commission shall prescribe rules and
regulations for the performance of any service or the furnishing of any
commodity of the character furnished or supplied by any public utility.
Whenever the Commission shall determine, after a hearing, that the public
convenience and necessity requires that interconnection or extension of
intrastate gas distribution or transmission pipelines or facilities is
necessary to insure that natural gas service is made available to Illinois
natural gas customers at rates which are just and reasonable, the
Commission shall determine the interconnection or extension of pipelines or
facilities which is necessary to provide such service and shall direct that
such facilities be established, according to a schedule set by the Commission.
The Commission shall direct that any utility supplying natural gas for such
interconnection or extension of intrastate gas distribution or transmission
pipelines or facilities shall recover all costs and charges related to the
interconnection or extension from the utility receiving such gas at no
increased cost to the customers of any utility supplying the gas. The
Commission is directed to report to the General Assembly by September 20,
1984, detailing its findings and the steps which it has taken to provide
for such intrastate interconnections or extensions.
(Source: P.A. 84-617.)
(220 ILCS 5/8-501.5)
Sec. 8-501.5. 
		Employees and independent contractors; background checks.
(a) Before hiring an employee or independent contractor to perform work
involving facilities used for the distribution of natural gas to customers,
a public utility shall, in accordance with Commission rules, require the
proposed employee or independent contractor to complete a certificate listing
the proposed employee's or contractor's violations of pertinent safety or
environmental laws.
(b) The Commission shall adopt rules establishing the requirements for
the certificates referred to in subsection (a).
(Source: P.A. 92-71, eff. 7-12-01.)
(220 ILCS 5/8-502) (from Ch. 111 2/3, par. 8-502)
Sec. 8-502. 
		
		Whenever the Commission, after a hearing had upon its own motion
or upon complaint, shall find that public convenience and necessity require
the use by one public utility of the conduits, subways, wires,
poles, pipes or other property or equipment, or any part thereof, on, over
or under any street or highway, belonging to another public utility, and
that such use will not prevent the owner or other users thereof from
performing their public duties nor result in irreparable injury to such
owner or other users of such conduits, subways, wires, poles, pipes
or other property or equipment, or in any substantial detriment to the
service, and that such public utilities have failed to agree upon such use
or the terms and conditions or compensation for the same, the Commission
may, by order, direct that such use be permitted and prescribe a reasonable
compensation and reasonable terms and conditions for such joint use. If
such use be directed, the public utility to whom the use is permitted shall
be liable to the owner or other users of such conduits, subways,
wires, poles, pipes or other property or equipment, for such damage as may
result therefrom to the property of such owner or other users thereof.
(Source: P.A. 84-1308.)
(220 ILCS 5/8-503) (from Ch. 111 2/3, par. 8-503)
Sec. 8-503. Whenever the Commission, after a hearing, shall find that
additions, extensions, repairs or improvements to, or changes in, the
existing plant, equipment, apparatus, facilities or other physical property
of any public utility or of any 2 or more public utilities are
necessary
and ought reasonably to be made or that a new structure or structures is or
are necessary and should be erected, to promote the security or convenience
of its employees or the public or promote the development of an effectively competitive electricity market, or in any other way to secure adequate
service or facilities, the Commission shall make and serve an order
authorizing or directing that such additions, extensions, repairs,
improvements or changes be made, or such structure or structures be erected
at the location, in the manner and within the time specified in said order;
provided, however, that the
Commission shall have no authority to order the construction,
addition or extension of any electric generating plant unless
the public utility requests a certificate for the construction
of the plant pursuant to Section 8-406 and in conjunction with
such request also requests the entry of an order under this
Section.
If any additions, extensions, repairs, improvements or changes, or any new
structure or structures, which the Commission has authorized or ordered to
be erected, require joint action by 2 or more public utilities, the
Commission shall notify the said public utilities that such additions,
extensions, repairs, improvements or changes or new structure or structures
have been authorized or ordered and that the same shall be made at the
joint cost whereupon the said public utilities shall have such reasonable
time as the Commission may grant within which to agree upon the
apportionment or division of cost of such additions, extensions, repairs,
improvements or changes or new structure or structures, which each shall
bear. If at the expiration of such time such public utilities shall fail to
file with the Commission a statement that an agreement has been made for a
division or apportionment of the cost or expense of such additions,
extensions, repairs, improvements or changes, or new structure or
structures, the Commission shall have authority, after further hearing, to
make an order fixing the proportion of such cost or expense to be borne by
each public utility and the manner in which the same shall be paid or secured.
Nothing in this Act shall prevent the Commission, upon its own motion
or upon petition, from ordering, after a hearing, the extension, construction,
connection or interconnection of plant, equipment, pipe, line, facilities
or other physical property of a public utility in whatever configuration the
Commission finds necessary to ensure that natural gas is made available to
consumers at no increased cost to the customers of the utility supplying the gas.
Whenever the Commission finds, after a hearing, that the public convenience
or necessity requires it, the Commission may order public utilities subject
to its jurisdiction to work jointly (1) for the purpose of purchasing and
distributing natural gas or gas substitutes, provided it shall not increase
the cost of gas to the customers of the participating utilities, or (2) for
any other reasonable purpose.
(Source: P.A. 95-700, eff. 11-9-07.)
(220 ILCS 5/8-504) (from Ch. 111 2/3, par. 8-504)
Sec. 8-504. 
		
		The Commission is authorized to make rules and regulations
concerning the conditions to be contained in and become a part of contracts
for public utility services, and any and all services concerning the same,
or connected therewith.
(Source: P.A. 84-617.)
(220 ILCS 5/8-505) (from Ch. 111 2/3, par. 8-505)
Sec. 8-505. 
		
		The Commission shall have power, after a hearing or without a
hearing as provided in this Section and upon
its own motion, or upon complaint, by general or special orders, rules
or regulations, or otherwise, to require every public utility to
maintain and operate its plant, equipment or other property in such
manner as to promote and safeguard the health and safety of its
employees, customers, and the public, and to this end to
prescribe, among other things, the installation, use, maintenance and
operation of appropriate safety or other devices or appliances, to establish
uniform or other standards of
equipment, and to require the performance of any other act which the
health or safety of its employees, customers or the public
may demand.
(Source: P.A. 84-617; 84-1025.)
(220 ILCS 5/8-505.1)
Sec. 8-505.1. Non-emergency vegetation management activities.
(a) Except as provided in subsections (b), (c), and (d), in conducting
its non-emergency vegetation management activities, an electric public utility
shall:
(1) Follow the most current tree care and maintenance     standard practices set forth in ANSI A300 published by the American National Standards Institute and the most current applicable Occupational Safety and Health Administration regulations regarding worker safety.
(2) Provide direct notice of vegetation management     activities no less than 21 days nor more than 90 days before the activities begin.
(A) If the vegetation management activities will         occur in an incorporated municipality, the notice must be given to the mayor or his or her designee.
(B) If the vegetation management activities will         occur in an unincorporated area, the notice must be given to the chairman of the county board or his or her designee.
(C) Affected customers shall be notified directly.
(D) Affected property owners shall be notified by         a published notice in a newspaper or newspapers in general circulation and widely distributed within the entire area in which the vegetation management activities notice will occur.
(E) Circuit maps or a description by common         address of the area to be affected by vegetation management activities must accompany any notice to a mayor or his or her designee or to a chairman of a county board or his or her designee.
The electric public utility giving the direct and     published notices required in this subsection (a)(2) shall provide notified customers and property owners with (i) a statement of the vegetation management activities planned, (ii) the address of a website and a toll-free telephone number at which a written disclosure of all dispute resolution opportunities and processes, rights, and remedies provided by the electric public utility may be obtained, (iii) a statement that the customer and the property owner may appeal the planned vegetation management activities through the electric public utility and the Illinois Commerce Commission, (iv) a toll-free telephone number through which communication may be had with a representative of the electric public utility regarding the vegetation management activities, and (v) the telephone number of the Consumer Affairs Officer of the Illinois Commerce Commission. The notice shall also include a statement that circuit maps and common addresses of the area to be affected by the vegetation management activities are on file with the office of the mayor of an affected municipality or his or her designee and the office of the county board chairman of an affected county or his or her designee.
The Commission shall have sole authority to
investigate, issue,
and hear complaints against the utility under this subsection (a).
(b) A public utility shall not be required to comply with the requirements
of subsection (d) or of paragraph (2) of
subsection (a) when it is taking
actions directly related to an emergency to restore reliable service after
interruptions of
service.
(c) A public utility shall not be required to comply with the requirements
of subsection (a) or (d) if there
is a franchise, contract, or written agreement between the public utility and
the municipality or county mandating specific vegetation management
practices.  If the franchise, contract, or written agreement between the
public utility and the municipality or county establishes requirements for
notice to the municipality, county, customers, and property owners, those
notice requirements shall control over the notice requirements of paragraph
(2) of subsection (a).  If the franchise, contract, or written
agreement between the public utility and the municipality or county does not
establish notice
requirements, the notice requirements contained in paragraph (2) of
subsection (a) shall control.
(d) If no franchise, contract, or written agreement
between a
utility
and a municipality mandates a specific vegetation management practice and the
municipality enacts
an ordinance establishing standards for non-emergency vegetation management
practices that are contrary to the
standards
established by this
Section and the vegetation management activities of the electric public
utility cost substantially more, as a direct consequence,
then the electric public utility may, before vegetation management activities
begin, apply to the municipality for an agreement to pay the additional cost.  When an application for an agreement is made to the
municipality, no vegetation management activities shall begin until the
municipality responds to the application by agreement or rejection or dispute
resolution proceedings are completed.  The application shall be supported by a
detailed specification of the difference between the standards established by
this Section and the contrary standards established by the municipal
ordinances and by a good faith bid or proposal obtained from a utility
contractor or
contractors quantifying the additional cost for performing the specification.
When the municipality receives the specification and the utility contractor's
bid or proposal, the municipality shall agree, reject, or initiate dispute
resolution proceedings regarding the application within 90
days after the application's receipt.  If the municipality does not act within
90
days or informs the utility that it will not agree, the electric public utility
may proceed and need not comply with the contrary ordinance standard.  When
there is a dispute regarding (i) the accuracy of the specification, (ii)
whether there is a conflict with the standards established by this
Section, or (iii) any aspect of the bid or proposal process, the Illinois
Commerce Commission shall hear and resolve the disputed matter or matters, with
the electric public utility having the burden of proof.  A municipality may
have a person trained in tree care and maintenance generally monitor and
discuss with the vegetation management supervisory personnel of the electric
public utility the
performance of the public utility's vegetation management activities without
any
claim for costs hereunder by the public utility arising therefrom.
The provisions of this Section shall not in any way diminish
or replace other civil or administrative remedies available to a customer or
class of customers or a property owner or class of property owners under
this Act.  This Section does not alter the jurisdiction of the Illinois
Commerce Commission in any manner except to obligate the Commission to
investigate, issue, and hear complaints against an electric public utility
as
provided in subsection (a)(2) and to hear and resolve disputed matters brought
to it as provided in this subsection.  Vegetation management activities by an
electric public utility shall not alter, trespass upon, or limit the rights of
any property owner.
(Source: P.A. 97-333, eff. 8-12-11.)
(220 ILCS 5/8-505.5)
Sec. 8-505.5. 
		Work on natural gas regulator or manometer. 
		The Commission
shall require, under such rules as it may prescribe, a public utility that is
performing work on a natural gas regulator or manometer containing mercury that
is used to provide natural gas service to test the immediate area around the
regulator or manometer for mercury before and after work is performed using
testing instruments of the type approved by the Commission.  Copies of the
test results, if requested, shall be provided to the occupant or owner of the
property upon which the regulator or manometer is located at the time the work
is performed.  The test results shall be available for inspection by the
Commission.
(Source: P.A. 92-71, eff. 7-12-01.)
(220 ILCS 5/8-506) (from Ch. 111 2/3, par. 8-506)
Sec. 8-506. 
		
		Whenever the Commission, after a hearing had upon its own
motion or upon complaint, shall determine that public convenience and
necessity require a physical connection for the establishment of a
continuous line of communication between any 2 or more public utilities for
the conveyance of messages or conversations, the Commission may, by order,
require that such connection be made. If such public utilities do not agree
upon the division between them of the cost of such physical connection or
connections, the Commission shall have authority, after further hearing, to
establish such division by supplemental order.
(Source: P.A. 84-617.)
(220 ILCS 5/8-507) (from Ch. 111 2/3, par. 8-507)
Sec. 8-507. 
Every public utility shall file with the Commission, under
such rules and regulations as the Commission may prescribe, a report of every
accident occurring to or on its plant, equipment, or other property of such
a nature to endanger the safety, health or property of any person.  Whenever
any accident occasions the loss of life or limb to any person, such public
utility shall immediately give notice to the Commission of the fact by the
speediest means of communication, whether telephone, electronic notification, or post.
The Commission
shall investigate all accidents occurring within this
State upon the property of any public utility or directly or indirectly
arising from or connected with its maintenance or operation, resulting in
loss of life or injury to person or property and requiring, in the judgment
of the Commission, investigation by it, and shall have the power to make
such order or recommendation with respect thereto as in its judgment may
seem just and reasonable.  Neither the order or recommendation of the
Commission nor any accident report filed with the Commission shall be
admitted in evidence in any action for damages based on or arising out of
the loss of life, or injury to person or property, in this Section referred
to.
(Source: P.A. 100-840, eff. 8-13-18.)
(220 ILCS 5/8-508) (from Ch. 111 2/3, par. 8-508)
Sec. 8-508. 
No public utility shall
abandon or discontinue any service or, in the case of an electric utility,
make any modification as herein defined, without first having secured the
approval of the Commission, except in case of assignment, transfer,
lease or sale of the whole or any part of its franchises, licenses,
permits, plant, equipment, business, or other property to any political
subdivision or municipal corporation of this State. In the case of the
assignment, transfer, lease or sale, in whole or in part, of any franchise,
license, permit, plant, equipment, business or other property to any
political subdivision or municipal corporation of this State, the public
utility shall notify the Commission of such transaction. "Modification" as
used in this Section means any change of fuel type which would result in an
annual net systemwide decreased use of 10% or more of coal mined in Illinois.
The Commission shall conduct public hearings on any request by a public
utility to make such modification and shall accept testimony from interested
parties qualified to provide evidence regarding the cost or cost savings
of the proposed modification as compared with the cost or cost savings of
alternative actions by the utility and shall consider the impact on employment
related to the production of coal in Illinois. Such hearings shall be commenced
 no later than 30 days after the filing of the request by the public utility
and shall be concluded within 120 days from the date of filing. The Commission
must issue its final determination within 60 days of the conclusion of the
hearing. In making its determination the Commission shall attach primary
weight to the cost or cost savings to the customers of the utility. In
granting its approval, the Commission may impose such terms, conditions
or requirements as in its judgment are necessary to protect the public
interest. Provided, however, that any public utility abandoning or
discontinuing service in pursuance of authority granted by the
Commission shall be deemed to have waived any and all objections to the
terms, conditions or requirements imposed by the Commission in that
regard. Provided, further, that nothing in this Section shall be
construed to limit the right of a public utility to discontinue service
to individual patrons in accordance with the effective rules,
regulations, and practices of such public utility.
The Commission, after a hearing upon its own motion or upon petition
of any public utility, shall have power by order to authorize or require
any public utility to curtail or discontinue service to individual
customers or classes thereof, or for specific purposes or uses, and
otherwise to regulate the furnishing of service, provided that preference
for service shall be given to those customers serving essential human needs and
governmental agencies performing law enforcement functions, whenever and to the
extent such action is required by the convenience and necessity of the
public during time of war, invasion, insurrection or martial law, or by
reason of a catastrophe, emergency, or shortage of fuel, supplies or
equipment employed or service furnished by such public utility;
provided, however, that an interim order, effective for a period not
exceeding 45 days, may be made without a hearing if the circumstances do
not reasonably permit the holding of a hearing. Orders for the
curtailment or discontinuance of service pursuant to this paragraph
shall not be continued in effect for any period beyond that which is
reasonably necessary, shall be vacated by the Commission as soon as
public convenience and necessity permit, and shall include such
arrangements for substitute service in the interim as the Commission in its
judgment may impose.  Every such order, during the
period it is in effect and for such further period, if any, as the
Commission may provide, shall have the effect of suspending the
operation of all prior orders or parts of orders of the Commission
inconsistent therewith. No public utility shall be held liable for any
damage resulting from any action taken, or any omission to act, pursuant
to or in compliance with any order under this paragraph for the
curtailment or discontinuance of service unless such order was procured
by the fraud of the public utility.
(Source: P.A. 102-457, eff. 1-1-22.)
(220 ILCS 5/8-508.1) (from Ch. 111 2/3, par. 8-508.1)
Sec. 8-508.1.  (a) As used in this Section:
(1) "Decommissioning" means the series of activities     undertaken at the time a nuclear power plant is permanently retired from service to ensure that the final entombment, decontamination, dismantlement, removal and disposal of the plant, including the plant site, and of any radioactive components and materials associated with the plant, is accomplished in compliance with all applicable Illinois and federal laws, and to ensure that such final disposition does not pose any threat to the public health and safety.
(2) "Decommissioning costs" means all reasonable     costs and expenses incurred in connection with the entombment, decontamination, dismantlement, removal and disposal of the structures, systems and components of a nuclear power plant at the time of decommissioning, including all expenses to be incurred in connection with the preparation for decommissioning, such as engineering and other planning expenses, and to be incurred after the actual decommissioning occurs, such as physical security and radiation monitoring expenses, less proceeds of insurance, salvage or resale of machinery, construction equipment or apparatus the cost of which was charged as a decommissioning expense.
(3) "Decommissioning trust" or "trust" means a     fiduciary account in a bank or other financial institution established to hold the decommissioning funds provided pursuant to subsection (b)(2) of this Section for the eventual purpose of paying decommissioning costs, which shall be separate from all other accounts and assets of the public utility establishing the trust.
(4) "Nuclear power plant" or "plant" means a nuclear     fission thermal power plant.  Each unit of a multi-unit site shall be considered a separate plant.
(b) By 90 days after the effective date of this amendatory Act of 1988,
or by the date that the unit satisfies the criteria used by the Internal
Revenue Service for determining when depreciation commences for federal
income tax purposes on a new generating unit, whichever is later, every
public utility that owns or operates, in whole or in part, a nuclear
power plant shall:
(1) establish 2 decommissioning trusts, which shall     be a "tax qualified" decommissioning trust and a "non-tax qualified" decommissioning trust and shall hold the decommissioning funds established by the public utility for all nuclear power plants pursuant to subsection (b)(2) of this Section;
(2) establish 2 decommissioning funds for each such     plant, each of which shall be held for a plant as a separate account in a decommissioning trust; and
(3) designate an independent trustee, subject to the     approval of the Commission, to administer each of the decommissioning trusts.
(c) The 2 decommissioning trusts shall be known as the "tax qualified"
decommissioning trust and the "non-tax qualified" decommissioning trust
respectively.  Each trust shall be established and maintained as follows:
(1) The "tax qualified" trust shall be established     and maintained in accordance with Section 468A of the Internal Revenue Code of 1986 or any successor thereto and shall be funded by the public utility for each such power plant through annual payments by the public utility that shall not exceed the maximum amount allowable as a deduction for federal income tax purposes for the year for which the payments were made, in accordance with Section 468A of the Internal Revenue Code of 1986 or any successor thereto.
(2) The "non-tax qualified" decommissioning trust     shall be funded by the public utility for each such power plant through annual payments by the public utility that shall consist of the difference between the total amounts of decommissioning expenses collected after the effective date of this amendatory Act of 1988 through rates and charges from the public utility's customers as provided by the Commission minus the amounts contributed to the "tax qualified" trust as provided by subsection (c)(1) of this Section and deductible for federal income tax purposes in accordance with Section 468A of the Internal Revenue Code of 1986 or any successor thereto.
(3) The following restrictions shall apply in regard     to administration of each decommissioning trust:
(i) Distributions may be made from a nuclear         decommissioning trust only to satisfy the liabilities of the public utility for nuclear decommissioning costs relating to the nuclear power plant for which the decommissioning fund was established and to pay administrative costs, income taxes and other incidental expenses of the trust.
(ii) Any assets in a nuclear decommissioning         trust that exceed the amount necessary to pay the nuclear decommissioning costs of the nuclear power plant for which the decommissioning fund was established shall be refunded to the public utility that established the fund for the purpose of refunds or credits, as soon as practicable, to the utility's customers.
(iii) In the event a public utility sells or         otherwise disposes of its direct ownership interest, or any part thereof, in a nuclear power plant with respect to which a nuclear decommissioning fund has been established, the assets of the fund shall be distributed to the public utility to the extent of the reductions in its liability for future decommissioning after taking into account the liabilities of the public utility for future decommissioning of such nuclear power plant and the liabilities that have been assumed by another entity.  The public utility shall, as soon as practicable, provide refunds or credits to its customers representing the full amount of the reductions in its liability for future decommissioning.
(iv) The trustee shall invest the "tax qualified"         trust assets only in secure assets that are prudent investments for assets held in trust and in such a way as to attempt to maximize the after-tax return on funds invested, subject to the limitations specified in Section 468A of the Internal Revenue Code of 1986 or any successor thereto.
(v) The trustee shall invest the "non-tax         qualified" trust assets only in secure assets that are prudent investments for assets held in trust and in such a way as to attempt to maximize the after-tax return on funds invested.  However the trustee shall not invest any portion of the "non-tax qualified" trust's funds in the securities or assets of any operator of a nuclear power plant.
(vi) The "non-tax qualified" trust shall be         subject to the prohibitions against self-dealing applicable to the "tax qualified" trust as specified in Section 468A of the Internal Revenue Code of 1986, or any successor thereto.
(vii) All income earned by the trust's funds         shall become a part of the trust's funds and subject to the provisions of this Section.
(viii) The Commission may adopt by rule or         regulation such further restrictions as it deems necessary for the sound management of the trust's funds, consistent with the purposes of this Section.
(d) By 90 days after the effective date of this amendatory Act of 1988,
the Commission shall determine an appropriate method to segregate, either
internally or externally, all decommissioning funds collected prior to the
effective date of this amendatory Act of 1988 by the utility from its
customers, and shall order any change in past decommissioning funding
methods that the Commission finds necessary.  In making its determination
of the appropriate funding method, the Commission shall give consideration
to, but not be limited by, all applicable federal regulations.  The change
in funding method shall be phased-in over an appropriate period of time.
(e) The trustee of a trust shall report annually to the Commission, or
more frequently if ordered by the Commission.  The report shall include:
(1) the trust's State and federal tax returns;
(2) a report on the trust's portfolio of investments     and the return thereon;
(3) the date and amount of payments received by the     trust from the public utility;
(4) a copy of all correspondence between the trust     and the Internal Revenue Service; and
(5) any other information the Commission orders the     trust to provide.
(f) A nuclear decommissioning trust established pursuant to this Section
shall be exempt from taxation in Illinois.
(g) Beginning on or before May 1, 2020, and every 2 years thereafter, the owner or operator of each nuclear power plant in this State shall provide the Commission with a copy of the nuclear decommissioning funding assurance status report submitted to the Nuclear Regulatory Commission and, as applicable, to the Federal Energy Regulatory Commission. Beginning June 1, 2020, and every 2 years thereafter, the Commission shall provide the General Assembly with a copy of the nuclear decommissioning funding assurance status report for shutdown units as submitted by the owner or operator of a nuclear power plant in this State to the Nuclear Regulatory Commission and, as applicable, to the Federal Energy Regulatory Commission.
(Source: P.A. 101-44, eff. 1-1-20.)
(220 ILCS 5/8-509) (from Ch. 111 2/3, par. 8-509)
Sec. 8-509. When necessary for the construction of any alterations,
additions, extensions or improvements ordered or authorized under Section 8-406.1 or
8-503 of this Act, any public utility may enter upon, take or
damage private property in the manner provided for by the law of eminent domain. If a public utility seeks relief under this Section in the same proceeding in which it seeks a certificate of public convenience and necessity under Section 8-406.1 of this Act, the Commission shall enter its order under this Section either as part of the Section 8-406.1 order or at the same time it enters the Section 8-406.1 order.  If a public utility seeks relief under this Section after the Commission enters its order in the Section 8-406.1 proceeding, the Commission shall issue its order under this Section within 45 days after the utility files its petition under this Section.
This Section applies to the exercise of eminent domain powers by
telephone companies or telecommunications carriers only when the facilities
to be constructed are intended to be used in whole or in part for providing
one or more intrastate telecommunications services classified as
"noncompetitive" under Section 13-502 in a tariff filed by the condemnor.
The exercise of eminent domain powers by telephone companies or
telecommunications carriers in all other cases shall be governed solely by
"An Act relating to the powers, duties and property of telephone
companies", approved May 16, 1903, as now or hereafter amended.
(Source: P.A. 100-840, eff. 8-13-18.)
(220 ILCS 5/8-509.5)
Sec. 8-509.5. Eminent domain. Notwithstanding any other provision of this Act, any power granted under this Act to acquire property by condemnation or eminent domain is subject to, and shall be exercised in accordance with, the Eminent Domain Act.
(Source: P.A. 94-1055, eff. 1-1-07.)
(220 ILCS 5/8-510) (from Ch. 111 2/3, par. 8-510)
Sec. 8-510. Land surveys and land use studies. For the purpose of making land surveys and land use studies, any public utility
that has been granted a certificate of public convenience and necessity
by, or received an order under Section 8-503 or 8-406.1 of this Act from, the
Commission may, 30 days after providing written notice to the
owner thereof by registered mail and after providing a second notice to the owner of record, as identified in the records of the relevant county tax assessor, by telephone or electronic mail or by registered mail in the event the property owner has not been notified by other means, at least 3 days, but not more than 15 days, prior to the stated date in the notice, identifying the date when land surveys and land use studies will first begin on their property and informing the landowner that they or their agent may be present when the land surveys or land use studies occur, enter upon the property of any owner who
has refused permission for entrance upon that property, but subject to
responsibility for all damages which may be inflicted thereby.
(Source: P.A. 99-399, eff. 8-18-15.)
(220 ILCS 5/8-511)
Sec. 8-511. (Repealed).
(Source: P.A. 96-37, eff. 7-13-09. Repealed by P.A. 96-40, eff. 7-13-09.)
(220 ILCS 5/8-512)
Sec. 8-512. Renewable energy access plan.
(a)   It is the policy of this State to promote cost-effective transmission system development that ensures reliability of the electric transmission system, lowers carbon emissions, minimizes long-term costs for consumers, and supports the electric policy goals of this State. The General Assembly finds that:
(1)   Transmission planning, primarily for     reliability purposes, but also for economic and public policy reasons is conducted by regional transmission organizations in which transmission-owning Illinois utilities and other stakeholders are members.
(2)   Order No. 1000 of the Federal Energy Regulatory     Commission requires regional transmission organizations to plan for transmission system needs in light of State public policies and to accept input from states during the transmission system planning processes.
(3)   The State of Illinois does not currently have a     comprehensive power and environmental policy planning process to identify transmission infrastructure needs that can serve as a vital input into the regional and interregional transmission organization planning processes conducted under Order No. 1000 and other laws and regulations.
(4)   This State is an electricity generation and     power transmission hub, and can leverage that position to invest in infrastructure that enables new and existing Illinois generators to meet the public policy goals of the State of Illinois and of interconnected states while cost-effectively supporting tens of thousands of jobs in the renewable energy sector in this State.
(5)   The nation has a need to readily access this     State's low-cost, clean electric power, and this State also desires access to clean energy resources in other states to develop and support its low-carbon economy and keep electricity prices low in Illinois and interconnected States.
(6)   Existing transmission infrastructure may     constrain the State's achievement of 100% renewable energy by 2050, the accelerated adoption of electric vehicles in a just and equitable way, and electrification of additional sectors of the Illinois economy.
(7)   Transmission system congestion within this     State and the regional transmission organizations serving this State limits the ability of this State's existing and new electric generation facilities that do not emit carbon dioxide, including renewable energy resources and zero emission facilities, to serve the public policy goals of this State and other states, which constrains investment in this State.
(8)   Investment in infrastructure to support     existing and new electric generation facilities that do not emit carbon dioxide, including renewable energy resources and zero emission facilities, stimulates significant economic development and job growth in this State, as well as creates environmental and public health benefits in this State.
(9)   Creating a forward-looking plan for this     State's electric transmission infrastructure, as opposed to relying on case-by-case development and repeated marginal upgrades, will achieve a lower-cost system for Illinois' electricity customers. A forward-looking plan can also help integrate and achieve a comprehensive set of objectives and multiple state, regional, and national policy goals.
(10)   Alternatives to overhead electric transmission     lines can achieve cost-effective resolution of system impacts and warrant investigation of the circumstances under which those alternatives should be considered and approved. The alternatives are likely to be beneficial as investment in electric transmission infrastructure moves forward.
(11)   Because transmission planning is conducted     primarily by the regional transmission organizations, the Commission should be advocating for the State's interests at the regional transmission organizations to ensure that such planning facilitates the State's policies and goals, including overall consumer savings, power system reliability, economic development, environmental improvement, and carbon reduction.
(b)   Consistent with the findings identified in subsection (a), the Commission shall open an investigation to develop and adopt a renewable energy access plan no later than December
31, 2022. To assist and support the Commission in the development of the plan, the Commission shall retain the services of technical and policy experts with relevant fields
of expertise, solicit technical and policy analysis from the public, and provide for a 120-day open public comment period after publication of a draft report, which shall be published no later than 90 days after the comment period ends. The plan shall, at a minimum, do the following:
(1)   designate renewable energy access plan zones     throughout this State in areas in which renewable energy resources and suitable land areas are sufficient for developing generating capacity from renewable energy technologies;
(2)   develop a plan to achieve transmission capacity     necessary to deliver the electric output from renewable energy technologies in the renewable energy access plan zones to customers in Illinois and other states in a manner that is most beneficial and cost-effective to customers;
(3)   use this State's position as an electricity     generation and power transmission hub to create new investment in this State's renewable energy resources;
(4)   consider programs, policies, and electric     transmission projects that can be adopted within this State that promote the cost-effective delivery of power from renewable energy resources interconnected to the bulk electric system to meet the renewable portfolio standard targets under subsection (c) of Section 1-75 of the Illinois Power Agency Act;
(5)   consider proposals to improve regional     transmission organizations' regional and interregional system planning processes, especially proposals that reduce costs and emissions, create jobs, and increase State and regional power system reliability to prevent high-cost outages that can endanger lives, and analyze  of how those proposals would improve reliability and cost-effective delivery of electricity in Illinois and the region;
(6)   make findings and policy recommendations based     on technical and policy analysis regarding locations of renewable energy access plan zones and the transmission system developments needed to cost-effectively achieve the public policy goals identified herein;
(6.5) make findings and policy recommendations based     on analysis regarding the impact of converting non-powered dams to hydropower dams relative to the alternative renewable energy resources; and
(7)   present the Commission's conclusions and     proposed recommendations based on its analysis and use the findings and policy recommendations to determine actions that the Commission should take.
(c)   No later than December 31, 2025, and every other year thereafter, the Commission shall open an investigation to develop and adopt an updated renewable energy access plan
that, at a minimum, evaluates the implementation and effectiveness of the renewable energy access plan, recommends improvements to the renewable energy access plan, and provides changes to transmission capacity necessary to deliver electric output from the renewable energy access plan zones.
(Source: P.A. 102-662, eff. 9-15-21; 103-380, eff. 1-1-24.)