Illinois 2023-2024 Regular Session

Illinois House Bill HB5514 Compare Versions

Only one version of the bill is available at this time.

Old	New	Differences
1	1	103RD GENERAL ASSEMBLY State of Illinois 2023 and 2024 HB5514 Introduced , by Rep. Jay Hoffman SYNOPSIS AS INTRODUCED: 20 ILCS 3855/1-520 ILCS 3855/1-1020 ILCS 3855/1-2020 ILCS 3855/1-75220 ILCS 5/16-108220 ILCS 5/16-111.5 Amends the Illinois Power Agency Act. Authorizes the Illinois Power Agency to develop a high voltage direct current (HVDC) renewable energy credit procurement for HVDC renewable energy credits. Provides that, within 120 days after the effective date of the amendatory Act, the Agency shall develop a HVDC renewable energy credit procurement plan limited to the procurement of HVDC renewable energy credits. Sets forth requirements and procedures for the procurement plan. Amends the Public Utilities Act to make conforming changes. LRB103 39335 CES 69496 b A BILL FOR 103RD GENERAL ASSEMBLY State of Illinois 2023 and 2024 HB5514 Introduced , by Rep. Jay Hoffman SYNOPSIS AS INTRODUCED: 20 ILCS 3855/1-520 ILCS 3855/1-1020 ILCS 3855/1-2020 ILCS 3855/1-75220 ILCS 5/16-108220 ILCS 5/16-111.5 20 ILCS 3855/1-5 20 ILCS 3855/1-10 20 ILCS 3855/1-20 20 ILCS 3855/1-75 220 ILCS 5/16-108 220 ILCS 5/16-111.5 Amends the Illinois Power Agency Act. Authorizes the Illinois Power Agency to develop a high voltage direct current (HVDC) renewable energy credit procurement for HVDC renewable energy credits. Provides that, within 120 days after the effective date of the amendatory Act, the Agency shall develop a HVDC renewable energy credit procurement plan limited to the procurement of HVDC renewable energy credits. Sets forth requirements and procedures for the procurement plan. Amends the Public Utilities Act to make conforming changes. LRB103 39335 CES 69496 b LRB103 39335 CES 69496 b A BILL FOR
2	2	103RD GENERAL ASSEMBLY State of Illinois 2023 and 2024 HB5514 Introduced , by Rep. Jay Hoffman SYNOPSIS AS INTRODUCED:
3	3	20 ILCS 3855/1-520 ILCS 3855/1-1020 ILCS 3855/1-2020 ILCS 3855/1-75220 ILCS 5/16-108220 ILCS 5/16-111.5 20 ILCS 3855/1-5 20 ILCS 3855/1-10 20 ILCS 3855/1-20 20 ILCS 3855/1-75 220 ILCS 5/16-108 220 ILCS 5/16-111.5
4	4	20 ILCS 3855/1-5
5	5	20 ILCS 3855/1-10
6	6	20 ILCS 3855/1-20
7	7	20 ILCS 3855/1-75
8	8	220 ILCS 5/16-108
9	9	220 ILCS 5/16-111.5
10	10	Amends the Illinois Power Agency Act. Authorizes the Illinois Power Agency to develop a high voltage direct current (HVDC) renewable energy credit procurement for HVDC renewable energy credits. Provides that, within 120 days after the effective date of the amendatory Act, the Agency shall develop a HVDC renewable energy credit procurement plan limited to the procurement of HVDC renewable energy credits. Sets forth requirements and procedures for the procurement plan. Amends the Public Utilities Act to make conforming changes.
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13	13	A BILL FOR
14	14	HB5514LRB103 39335 CES 69496 b HB5514 LRB103 39335 CES 69496 b
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16	16	1 AN ACT concerning regulation.
17	17	2 Be it enacted by the People of the State of Illinois,
18	18	3 represented in the General Assembly:
19	19	4 Section 5. The Illinois Power Agency Act is amended by
20	20	5 changing Sections 1-5, 1-10, 1-20, and 1-75 as follows:
21	21	6 (20 ILCS 3855/1-5)
22	22	7 Sec. 1-5. Legislative declarations and findings. The
23	23	8 General Assembly finds and declares:
24	24	9 (1) The health, welfare, and prosperity of all
25	25	10 Illinois residents require the provision of adequate,
26	26	11 reliable, affordable, efficient, and environmentally
27	27	12 sustainable electric service at the lowest total cost over
28	28	13 time, taking into account any benefits of price stability.
29	29	14 (1.5) To provide the highest quality of life for the
30	30	15 residents of Illinois and to provide for a clean and
31	31	16 healthy environment, it is the policy of this State to
32	32	17 rapidly transition to 100% clean energy by 2050.
33	33	18 (2) (Blank).
34	34	19 (3) (Blank).
35	35	20 (4) It is necessary to improve the process of
36	36	21 procuring electricity to serve Illinois residents, to
37	37	22 promote investment in energy efficiency and
38	38	23 demand-response measures, and to maintain and support
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42	42	103RD GENERAL ASSEMBLY State of Illinois 2023 and 2024 HB5514 Introduced , by Rep. Jay Hoffman SYNOPSIS AS INTRODUCED:
43	43	20 ILCS 3855/1-520 ILCS 3855/1-1020 ILCS 3855/1-2020 ILCS 3855/1-75220 ILCS 5/16-108220 ILCS 5/16-111.5 20 ILCS 3855/1-5 20 ILCS 3855/1-10 20 ILCS 3855/1-20 20 ILCS 3855/1-75 220 ILCS 5/16-108 220 ILCS 5/16-111.5
44	44	20 ILCS 3855/1-5
45	45	20 ILCS 3855/1-10
46	46	20 ILCS 3855/1-20
47	47	20 ILCS 3855/1-75
48	48	220 ILCS 5/16-108
49	49	220 ILCS 5/16-111.5
50	50	Amends the Illinois Power Agency Act. Authorizes the Illinois Power Agency to develop a high voltage direct current (HVDC) renewable energy credit procurement for HVDC renewable energy credits. Provides that, within 120 days after the effective date of the amendatory Act, the Agency shall develop a HVDC renewable energy credit procurement plan limited to the procurement of HVDC renewable energy credits. Sets forth requirements and procedures for the procurement plan. Amends the Public Utilities Act to make conforming changes.
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53	53	A BILL FOR
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59	59	20 ILCS 3855/1-5
60	60	20 ILCS 3855/1-10
61	61	20 ILCS 3855/1-20
62	62	20 ILCS 3855/1-75
63	63	220 ILCS 5/16-108
64	64	220 ILCS 5/16-111.5
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83	83	1 development of clean coal technologies, generation
84	84	2 resources that operate at all hours of the day and under
85	85	3 all weather conditions, zero emission facilities, and
86	86	4 renewable resources.
87	87	5 (5) Procuring a diverse electricity supply portfolio
88	88	6 will ensure the lowest total cost over time for adequate,
89	89	7 reliable, efficient, and environmentally sustainable
90	90	8 electric service.
91	91	9 (6) Including renewable resources and zero emission
92	92	10 credits from zero emission facilities in that portfolio
93	93	11 will reduce long-term direct and indirect costs to
94	94	12 consumers by decreasing environmental impacts and by
95	95	13 avoiding or delaying the need for new generation,
96	96	14 transmission, and distribution infrastructure. Developing
97	97	15 new renewable energy resources in Illinois, including
98	98	16 brownfield solar projects and community solar projects,
99	99	17 will help to diversify Illinois electricity supply, avoid
100	100	18 and reduce pollution, reduce peak demand, and enhance
101	101	19 public health and well-being of Illinois residents.
102	102	20 (7) Developing community solar projects in Illinois
103	103	21 will help to expand access to renewable energy resources
104	104	22 to more Illinois residents.
105	105	23 (8) Developing brownfield solar projects in Illinois
106	106	24 will help return blighted or contaminated land to
107	107	25 productive use while enhancing public health and the
108	108	26 well-being of Illinois residents, including those in
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119	119	1 environmental justice communities.
120	120	2 (9) Energy efficiency, demand-response measures, zero
121	121	3 emission energy, and renewable energy are resources
122	122	4 currently underused in Illinois. These resources should be
123	123	5 used, when cost effective, to reduce costs to consumers,
124	124	6 improve reliability, and improve environmental quality and
125	125	7 public health.
126	126	8 (10) The State should encourage the use of advanced
127	127	9 clean coal technologies that capture and sequester carbon
128	128	10 dioxide emissions to advance environmental protection
129	129	11 goals and to demonstrate the viability of coal and
130	130	12 coal-derived fuels in a carbon-constrained economy.
131	131	13 (10.5) The State should encourage the development of
132	132	14 interregional high voltage direct current (HVDC)
133	133	15 transmission lines that benefit Illinois. All ratepayers
134	134	16 in the State served by the regional transmission
135	135	17 organization where the HVDC converter station is
136	136	18 interconnected benefit from the long-term price stability
137	137	19 and market access provided by interregional HVDC
138	138	20 transmission facilities. The benefits to Illinois include:
139	139	21 reduction in wholesale power prices; access to lower-cost
140	140	22 markets; enabling the integration of additional renewable
141	141	23 generating units within the State through near
142	142	24 instantaneous dispatchability and the provision of
143	143	25 ancillary services; creating good-paying union jobs in
144	144	26 Illinois; and, enhancing grid reliability and climate
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155	155	1 resilience via HVDC facilities that are installed
156	156	2 underground.
157	157	3 (10.6) The health, welfare, and safety of the people
158	158	4 of the State are advanced by developing new HVDC
159	159	5 transmission lines predominantly along transportation
160	160	6 rights-of-way, with an HVDC converter station that is
161	161	7 located in the service territory of a public utility as
162	162	8 defined in Section 3-105 of the Public Utilities Act
163	163	9 serving more than 3,000,000 retail customers, and with a
164	164	10 project labor agreement as defined in Section 1-10 of this
165	165	11 Act.
166	166	12 (10.8) Procurement of renewable resources transmitted
167	167	13 over new HVDC transmission lines benefits all ratepayers
168	168	14 by decarbonizing the Illinois economy by providing as much
169	169	15 as 17,958,000 megawatt-hours of diversified renewable
170	170	16 energy resources annually while improving reliability
171	171	17 through fully dispatchable high-voltage direct current
172	172	18 transmission facilities that cannot be provided through
173	173	19 development of local renewable generation or transmission
174	174	20 alone.
175	175	21 (11) The General Assembly enacted Public Act 96-0795
176	176	22 to reform the State's purchasing processes, recognizing
177	177	23 that government procurement is susceptible to abuse if
178	178	24 structural and procedural safeguards are not in place to
179	179	25 ensure independence, insulation, oversight, and
180	180	26 transparency.
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191	191	1 (12) The principles that underlie the procurement
192	192	2 reform legislation apply also in the context of power
193	193	3 purchasing.
194	194	4 (13) To ensure that the benefits of installing
195	195	5 renewable resources are available to all Illinois
196	196	6 residents and located across the State, subject to
197	197	7 appropriation, it is necessary for the Agency to provide
198	198	8 public information and educational resources on how
199	199	9 residents can benefit from the expansion of renewable
200	200	10 energy in Illinois and participate in the Illinois Solar
201	201	11 for All Program established in Section 1-56, the
202	202	12 Adjustable Block program established in Section 1-75, the
203	203	13 job training programs established by paragraph (1) of
204	204	14 subsection (a) of Section 16-108.12 of the Public
205	205	15 Utilities Act, and the programs and resources established
206	206	16 by the Energy Transition Act.
207	207	17 The General Assembly therefore finds that it is necessary
208	208	18 to create the Illinois Power Agency and that the goals and
209	209	19 objectives of that Agency are to accomplish each of the
210	210	20 following:
211	211	21 (A) Develop electricity procurement plans to ensure
212	212	22 adequate, reliable, affordable, efficient, and
213	213	23 environmentally sustainable electric service at the lowest
214	214	24 total cost over time, taking into account any benefits of
215	215	25 price stability, for electric utilities that on December
216	216	26 31, 2005 provided electric service to at least 100,000
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227	227	1 customers in Illinois and for small multi-jurisdictional
228	228	2 electric utilities that (i) on December 31, 2005 served
229	229	3 less than 100,000 customers in Illinois and (ii) request a
230	230	4 procurement plan for their Illinois jurisdictional load.
231	231	5 The procurement plan shall be updated on an annual basis
232	232	6 and shall include renewable energy resources and,
233	233	7 beginning with the delivery year commencing June 1, 2017,
234	234	8 zero emission credits from zero emission facilities
235	235	9 sufficient to achieve the standards specified in this Act.
236	236	10 (B) Conduct the competitive procurement processes
237	237	11 identified in this Act.
238	238	12 (C) Develop electric generation and co-generation
239	239	13 facilities that use indigenous coal or renewable
240	240	14 resources, or both, financed with bonds issued by the
241	241	15 Illinois Finance Authority.
242	242	16 (D) Supply electricity from the Agency's facilities at
243	243	17 cost to one or more of the following: municipal electric
244	244	18 systems, governmental aggregators, or rural electric
245	245	19 cooperatives in Illinois.
246	246	20 (E) Ensure that the process of power procurement is
247	247	21 conducted in an ethical and transparent fashion, immune
248	248	22 from improper influence.
249	249	23 (F) Continue to review its policies and practices to
250	250	24 determine how best to meet its mission of providing the
251	251	25 lowest cost power to the greatest number of people, at any
252	252	26 given point in time, in accordance with applicable law.
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263	263	1 (G) Operate in a structurally insulated, independent,
264	264	2 and transparent fashion so that nothing impedes the
265	265	3 Agency's mission to secure power at the best prices the
266	266	4 market will bear, provided that the Agency meets all
267	267	5 applicable legal requirements.
268	268	6 (H) Implement renewable energy procurement and
269	269	7 training programs throughout the State to diversify
270	270	8 Illinois electricity supply, improve reliability, avoid
271	271	9 and reduce pollution, reduce peak demand, and enhance
272	272	10 public health and well-being of Illinois residents,
273	273	11 including low-income residents.
274	274	12 (I) Implement procurement of high voltage direct
275	275	13 current renewable energy credits.
276	276	14 (Source: P.A. 102-662, eff. 9-15-21.)
277	277	15 (20 ILCS 3855/1-10)
278	278	16 Sec. 1-10. Definitions.
279	279	17 "Agency" means the Illinois Power Agency.
280	280	18 "Agency loan agreement" means any agreement pursuant to
281	281	19 which the Illinois Finance Authority agrees to loan the
282	282	20 proceeds of revenue bonds issued with respect to a project to
283	283	21 the Agency upon terms providing for loan repayment
284	284	22 installments at least sufficient to pay when due all principal
285	285	23 of, interest and premium, if any, on those revenue bonds, and
286	286	24 providing for maintenance, insurance, and other matters in
287	287	25 respect of the project.
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298	298	1 "Authority" means the Illinois Finance Authority.
299	299	2 "Brownfield site photovoltaic project" means photovoltaics
300	300	3 that are either:
301	301	4 (1) interconnected to an electric utility as defined
302	302	5 in this Section, a municipal utility as defined in this
303	303	6 Section, a public utility as defined in Section 3-105 of
304	304	7 the Public Utilities Act, or an electric cooperative as
305	305	8 defined in Section 3-119 of the Public Utilities Act and
306	306	9 located at a site that is regulated by any of the following
307	307	10 entities under the following programs:
308	308	11 (A) the United States Environmental Protection
309	309	12 Agency under the federal Comprehensive Environmental
310	310	13 Response, Compensation, and Liability Act of 1980, as
311	311	14 amended;
312	312	15 (B) the United States Environmental Protection
313	313	16 Agency under the Corrective Action Program of the
314	314	17 federal Resource Conservation and Recovery Act, as
315	315	18 amended;
316	316	19 (C) the Illinois Environmental Protection Agency
317	317	20 under the Illinois Site Remediation Program; or
318	318	21 (D) the Illinois Environmental Protection Agency
319	319	22 under the Illinois Solid Waste Program; or
320	320	23 (2) located at the site of a coal mine that has
321	321	24 permanently ceased coal production, permanently halted any
322	322	25 re-mining operations, and is no longer accepting any coal
323	323	26 combustion residues; has both completed all clean-up and
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334	334	1 remediation obligations under the federal Surface Mining
335	335	2 and Reclamation Act of 1977 and all applicable Illinois
336	336	3 rules and any other clean-up, remediation, or ongoing
337	337	4 monitoring to safeguard the health and well-being of the
338	338	5 people of the State of Illinois, as well as demonstrated
339	339	6 compliance with all applicable federal and State
340	340	7 environmental rules and regulations, including, but not
341	341	8 limited, to 35 Ill. Adm. Code Part 845 and any rules for
342	342	9 historic fill of coal combustion residuals, including any
343	343	10 rules finalized in Subdocket A of Illinois Pollution
344	344	11 Control Board docket R2020-019.
345	345	12 "Clean coal facility" means an electric generating
346	346	13 facility that uses primarily coal as a feedstock and that
347	347	14 captures and sequesters carbon dioxide emissions at the
348	348	15 following levels: at least 50% of the total carbon dioxide
349	349	16 emissions that the facility would otherwise emit if, at the
350	350	17 time construction commences, the facility is scheduled to
351	351	18 commence operation before 2016, at least 70% of the total
352	352	19 carbon dioxide emissions that the facility would otherwise
353	353	20 emit if, at the time construction commences, the facility is
354	354	21 scheduled to commence operation during 2016 or 2017, and at
355	355	22 least 90% of the total carbon dioxide emissions that the
356	356	23 facility would otherwise emit if, at the time construction
357	357	24 commences, the facility is scheduled to commence operation
358	358	25 after 2017. The power block of the clean coal facility shall
359	359	26 not exceed allowable emission rates for sulfur dioxide,
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370	370	1 nitrogen oxides, carbon monoxide, particulates and mercury for
371	371	2 a natural gas-fired combined-cycle facility the same size as
372	372	3 and in the same location as the clean coal facility at the time
373	373	4 the clean coal facility obtains an approved air permit. All
374	374	5 coal used by a clean coal facility shall have high volatile
375	375	6 bituminous rank and greater than 1.7 pounds of sulfur per
376	376	7 million Btu content, unless the clean coal facility does not
377	377	8 use gasification technology and was operating as a
378	378	9 conventional coal-fired electric generating facility on June
379	379	10 1, 2009 (the effective date of Public Act 95-1027).
380	380	11 "Clean coal SNG brownfield facility" means a facility that
381	381	12 (1) has commenced construction by July 1, 2015 on an urban
382	382	13 brownfield site in a municipality with at least 1,000,000
383	383	14 residents; (2) uses a gasification process to produce
384	384	15 substitute natural gas; (3) uses coal as at least 50% of the
385	385	16 total feedstock over the term of any sourcing agreement with a
386	386	17 utility and the remainder of the feedstock may be either
387	387	18 petroleum coke or coal, with all such coal having a high
388	388	19 bituminous rank and greater than 1.7 pounds of sulfur per
389	389	20 million Btu content unless the facility reasonably determines
390	390	21 that it is necessary to use additional petroleum coke to
391	391	22 deliver additional consumer savings, in which case the
392	392	23 facility shall use coal for at least 35% of the total feedstock
393	393	24 over the term of any sourcing agreement; and (4) captures and
394	394	25 sequesters at least 85% of the total carbon dioxide emissions
395	395	26 that the facility would otherwise emit.
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406	406	1 "Clean coal SNG facility" means a facility that uses a
407	407	2 gasification process to produce substitute natural gas, that
408	408	3 sequesters at least 90% of the total carbon dioxide emissions
409	409	4 that the facility would otherwise emit, that uses at least 90%
410	410	5 coal as a feedstock, with all such coal having a high
411	411	6 bituminous rank and greater than 1.7 pounds of sulfur per
412	412	7 million Btu content, and that has a valid and effective permit
413	413	8 to construct emission sources and air pollution control
414	414	9 equipment and approval with respect to the federal regulations
415	415	10 for Prevention of Significant Deterioration of Air Quality
416	416	11 (PSD) for the plant pursuant to the federal Clean Air Act;
417	417	12 provided, however, a clean coal SNG brownfield facility shall
418	418	13 not be a clean coal SNG facility.
419	419	14 "Clean energy" means energy generation that is 90% or
420	420	15 greater free of carbon dioxide emissions.
421	421	16 "Commission" means the Illinois Commerce Commission.
422	422	17 "Community renewable generation project" means an electric
423	423	18 generating facility that:
424	424	19 (1) is powered by wind, solar thermal energy,
425	425	20 photovoltaic cells or panels, biodiesel, crops and
426	426	21 untreated and unadulterated organic waste biomass, and
427	427	22 hydropower that does not involve new construction of dams;
428	428	23 (2) is interconnected at the distribution system level
429	429	24 of an electric utility as defined in this Section, a
430	430	25 municipal utility as defined in this Section that owns or
431	431	26 operates electric distribution facilities, a public
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442	442	1 utility as defined in Section 3-105 of the Public
443	443	2 Utilities Act, or an electric cooperative, as defined in
444	444	3 Section 3-119 of the Public Utilities Act;
445	445	4 (3) credits the value of electricity generated by the
446	446	5 facility to the subscribers of the facility; and
447	447	6 (4) is limited in nameplate capacity to less than or
448	448	7 equal to 5,000 kilowatts.
449	449	8 "Costs incurred in connection with the development and
450	450	9 construction of a facility" means:
451	451	10 (1) the cost of acquisition of all real property,
452	452	11 fixtures, and improvements in connection therewith and
453	453	12 equipment, personal property, and other property, rights,
454	454	13 and easements acquired that are deemed necessary for the
455	455	14 operation and maintenance of the facility;
456	456	15 (2) financing costs with respect to bonds, notes, and
457	457	16 other evidences of indebtedness of the Agency;
458	458	17 (3) all origination, commitment, utilization,
459	459	18 facility, placement, underwriting, syndication, credit
460	460	19 enhancement, and rating agency fees;
461	461	20 (4) engineering, design, procurement, consulting,
462	462	21 legal, accounting, title insurance, survey, appraisal,
463	463	22 escrow, trustee, collateral agency, interest rate hedging,
464	464	23 interest rate swap, capitalized interest, contingency, as
465	465	24 required by lenders, and other financing costs, and other
466	466	25 expenses for professional services; and
467	467	26 (5) the costs of plans, specifications, site study and
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478	478	1 investigation, installation, surveys, other Agency costs
479	479	2 and estimates of costs, and other expenses necessary or
480	480	3 incidental to determining the feasibility of any project,
481	481	4 together with such other expenses as may be necessary or
482	482	5 incidental to the financing, insuring, acquisition, and
483	483	6 construction of a specific project and starting up,
484	484	7 commissioning, and placing that project in operation.
485	485	8 "Delivery services" has the same definition as found in
486	486	9 Section 16-102 of the Public Utilities Act.
487	487	10 "Delivery year" means the consecutive 12-month period
488	488	11 beginning June 1 of a given year and ending May 31 of the
489	489	12 following year.
490	490	13 "Department" means the Department of Commerce and Economic
491	491	14 Opportunity.
492	492	15 "Director" means the Director of the Illinois Power
493	493	16 Agency.
494	494	17 "Demand-response" means measures that decrease peak
495	495	18 electricity demand or shift demand from peak to off-peak
496	496	19 periods.
497	497	20 "Distributed renewable energy generation device" means a
498	498	21 device that is:
499	499	22 (1) powered by wind, solar thermal energy,
500	500	23 photovoltaic cells or panels, biodiesel, crops and
501	501	24 untreated and unadulterated organic waste biomass, tree
502	502	25 waste, and hydropower that does not involve new
503	503	26 construction of dams, waste heat to power systems, or
504	504
505	505
506	506
507	507
508	508
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510	510
511	511
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513	513	HB5514 - 14 - LRB103 39335 CES 69496 b
514	514	1 qualified combined heat and power systems;
515	515	2 (2) interconnected at the distribution system level of
516	516	3 either an electric utility as defined in this Section, a
517	517	4 municipal utility as defined in this Section that owns or
518	518	5 operates electric distribution facilities, or a rural
519	519	6 electric cooperative as defined in Section 3-119 of the
520	520	7 Public Utilities Act;
521	521	8 (3) located on the customer side of the customer's
522	522	9 electric meter and is primarily used to offset that
523	523	10 customer's electricity load; and
524	524	11 (4) (blank).
525	525	12 "Energy efficiency" means measures that reduce the amount
526	526	13 of electricity or natural gas consumed in order to achieve a
527	527	14 given end use. "Energy efficiency" includes voltage
528	528	15 optimization measures that optimize the voltage at points on
529	529	16 the electric distribution voltage system and thereby reduce
530	530	17 electricity consumption by electric customers' end use
531	531	18 devices. "Energy efficiency" also includes measures that
532	532	19 reduce the total Btus of electricity, natural gas, and other
533	533	20 fuels needed to meet the end use or uses.
534	534	21 "Electric utility" has the same definition as found in
535	535	22 Section 16-102 of the Public Utilities Act.
536	536	23 "Equity investment eligible community" or "eligible
537	537	24 community" are synonymous and mean the geographic areas
538	538	25 throughout Illinois which would most benefit from equitable
539	539	26 investments by the State designed to combat discrimination.
540	540
541	541
542	542
543	543
544	544
545	545	HB5514 - 14 - LRB103 39335 CES 69496 b
546	546
547	547
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549	549	HB5514 - 15 - LRB103 39335 CES 69496 b
550	550	1 Specifically, the eligible communities shall be defined as the
551	551	2 following areas:
552	552	3 (1) R3 Areas as established pursuant to Section 10-40
553	553	4 of the Cannabis Regulation and Tax Act, where residents
554	554	5 have historically been excluded from economic
555	555	6 opportunities, including opportunities in the energy
556	556	7 sector; and
557	557	8 (2) environmental justice communities, as defined by
558	558	9 the Illinois Power Agency pursuant to the Illinois Power
559	559	10 Agency Act, where residents have historically been subject
560	560	11 to disproportionate burdens of pollution, including
561	561	12 pollution from the energy sector.
562	562	13 "Equity eligible persons" or "eligible persons" means
563	563	14 persons who would most benefit from equitable investments by
564	564	15 the State designed to combat discrimination, specifically:
565	565	16 (1) persons who graduate from or are current or former
566	566	17 participants in the Clean Jobs Workforce Network Program,
567	567	18 the Clean Energy Contractor Incubator Program, the
568	568	19 Illinois Climate Works Preapprenticeship Program,
569	569	20 Returning Residents Clean Jobs Training Program, or the
570	570	21 Clean Energy Primes Contractor Accelerator Program, and
571	571	22 the solar training pipeline and multi-cultural jobs
572	572	23 program created in paragraphs (a)(1) and (a)(3) of Section
573	573	24 16-208.12 of the Public Utilities Act;
574	574	25 (2) persons who are graduates of or currently enrolled
575	575	26 in the foster care system;
576	576
577	577
578	578
579	579
580	580
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582	582
583	583
584	584	HB5514- 16 -LRB103 39335 CES 69496 b HB5514 - 16 - LRB103 39335 CES 69496 b
585	585	HB5514 - 16 - LRB103 39335 CES 69496 b
586	586	1 (3) persons who were formerly incarcerated;
587	587	2 (4) persons whose primary residence is in an equity
588	588	3 investment eligible community.
589	589	4 "Equity eligible contractor" means a business that is
590	590	5 majority-owned by eligible persons, or a nonprofit or
591	591	6 cooperative that is majority-governed by eligible persons, or
592	592	7 is a natural person that is an eligible person offering
593	593	8 personal services as an independent contractor.
594	594	9 "Facility" means an electric generating unit or a
595	595	10 co-generating unit that produces electricity along with
596	596	11 related equipment necessary to connect the facility to an
597	597	12 electric transmission or distribution system.
598	598	13 "General contractor" means the entity or organization with
599	599	14 main responsibility for the building of a construction project
600	600	15 and who is the party signing the prime construction contract
601	601	16 for the project.
602	602	17 "Governmental aggregator" means one or more units of local
603	603	18 government that individually or collectively procure
604	604	19 electricity to serve residential retail electrical loads
605	605	20 located within its or their jurisdiction.
606	606	21 "High voltage direct current converter station" means the
607	607	22 collection of equipment that converts direct current energy
608	608	23 from a high voltage direct current transmission line into
609	609	24 alternating current using Voltage Source Conversion technology
610	610	25 and that is interconnected with transmission or distribution
611	611	26 assets located in Illinois.
612	612
613	613
614	614
615	615
616	616
617	617	HB5514 - 16 - LRB103 39335 CES 69496 b
618	618
619	619
620	620	HB5514- 17 -LRB103 39335 CES 69496 b HB5514 - 17 - LRB103 39335 CES 69496 b
621	621	HB5514 - 17 - LRB103 39335 CES 69496 b
622	622	1 "High voltage direct current renewable energy credit"
623	623	2 means a renewable energy credit associated with a renewable
624	624	3 energy resource where the renewable energy resource has
625	625	4 entered into a contract to transmit the energy associated with
626	626	5 such renewable energy credit over high voltage direct current
627	627	6 transmission facilities.
628	628	7 "High voltage direct current transmission facilities"
629	629	8 means the collection of installed equipment that converts
630	630	9 alternating current energy in one location to direct current
631	631	10 and transmits that direct current energy to a high voltage
632	632	11 direct current converter station using Voltage Source
633	633	12 Conversion technology. "High voltage direct current
634	634	13 transmission facilities" includes the high voltage direct
635	635	14 current converter station itself and associated high voltage
636	636	15 direct current transmission lines. Notwithstanding the
637	637	16 preceding, after September 15, 2021 (the effective date of
638	638	17 Public Act 102-662), an otherwise qualifying collection of
639	639	18 equipment does not qualify as high voltage direct current
640	640	19 transmission facilities unless: (i) its developer entered into
641	641	20 a project labor agreement, (ii) more than 100 miles of its
642	642	21 Illinois footprint is built underground, (iii) the facilities
643	643	22 are is capable of transmitting electricity at 525kv or above,
644	644	23 and (iv) the facilities include with an Illinois converter
645	645	24 station physically located in and interconnected in the
646	646	25 Illinois footprint region of the PJM Interconnection, LLC, and
647	647	26 the system does not operate as a public utility in Illinois, as
648	648
649	649
650	650
651	651
652	652
653	653	HB5514 - 17 - LRB103 39335 CES 69496 b
654	654
655	655
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657	657	HB5514 - 18 - LRB103 39335 CES 69496 b
658	658	1 that term is defined in Section 3-105 of the Public Utilities
659	659	2 Act.
660	660	3 "Hydropower" means any method of electricity generation or
661	661	4 storage that results from the flow of water, including
662	662	5 impoundment facilities, diversion facilities, and pumped
663	663	6 storage facilities.
664	664	7 "Index price" means the real-time energy settlement price
665	665	8 at the applicable Illinois trading hub, such as PJM-NIHUB or
666	666	9 MISO-IL, for a given settlement period.
667	667	10 "Indexed renewable energy credit" means a tradable credit
668	668	11 that represents the environmental attributes of one megawatt
669	669	12 hour of energy produced from a renewable energy resource, the
670	670	13 price of which shall be calculated by subtracting the strike
671	671	14 price offered by a new utility-scale wind project or a new
672	672	15 utility-scale photovoltaic project from the index price in a
673	673	16 given settlement period.
674	674	17 "Indexed renewable energy credit counterparty" has the
675	675	18 same meaning as "public utility" as defined in Section 3-105
676	676	19 of the Public Utilities Act.
677	677	20 "Local government" means a unit of local government as
678	678	21 defined in Section 1 of Article VII of the Illinois
679	679	22 Constitution.
680	680	23 "Modernized" or "retooled" means the construction, repair,
681	681	24 maintenance, or significant expansion of turbines and existing
682	682	25 hydropower dams.
683	683	26 "Municipality" means a city, village, or incorporated
684	684
685	685
686	686
687	687
688	688
689	689	HB5514 - 18 - LRB103 39335 CES 69496 b
690	690
691	691
692	692	HB5514- 19 -LRB103 39335 CES 69496 b HB5514 - 19 - LRB103 39335 CES 69496 b
693	693	HB5514 - 19 - LRB103 39335 CES 69496 b
694	694	1 town.
695	695	2 "Municipal utility" means a public utility owned and
696	696	3 operated by any subdivision or municipal corporation of this
697	697	4 State.
698	698	5 "Nameplate capacity" means the aggregate inverter
699	699	6 nameplate capacity in kilowatts AC.
700	700	7 "Person" means any natural person, firm, partnership,
701	701	8 corporation, either domestic or foreign, company, association,
702	702	9 limited liability company, joint stock company, or association
703	703	10 and includes any trustee, receiver, assignee, or personal
704	704	11 representative thereof.
705	705	12 "Project" means the planning, bidding, and construction of
706	706	13 a facility.
707	707	14 "Project labor agreement" means a pre-hire collective
708	708	15 bargaining agreement that covers all terms and conditions of
709	709	16 employment on a specific construction project and must include
710	710	17 the following:
711	711	18 (1) provisions establishing the minimum hourly wage
712	712	19 for each class of labor organization employee;
713	713	20 (2) provisions establishing the benefits and other
714	714	21 compensation for each class of labor organization
715	715	22 employee;
716	716	23 (3) provisions establishing that no strike or disputes
717	717	24 will be engaged in by the labor organization employees;
718	718	25 (4) provisions establishing that no lockout or
719	719	26 disputes will be engaged in by the general contractor
720	720
721	721
722	722
723	723
724	724
725	725	HB5514 - 19 - LRB103 39335 CES 69496 b
726	726
727	727
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729	729	HB5514 - 20 - LRB103 39335 CES 69496 b
730	730	1 building the project; and
731	731	2 (5) provisions for minorities and women, as defined
732	732	3 under the Business Enterprise for Minorities, Women, and
733	733	4 Persons with Disabilities Act, setting forth goals for
734	734	5 apprenticeship hours to be performed by minorities and
735	735	6 women and setting forth goals for total hours to be
736	736	7 performed by underrepresented minorities and women.
737	737	8 A labor organization and the general contractor building
738	738	9 the project shall have the authority to include other terms
739	739	10 and conditions as they deem necessary.
740	740	11 "Public utility" has the same definition as found in
741	741	12 Section 3-105 of the Public Utilities Act.
742	742	13 "Qualified combined heat and power systems" means systems
743	743	14 that, either simultaneously or sequentially, produce
744	744	15 electricity and useful thermal energy from a single fuel
745	745	16 source. Such systems are eligible for "renewable energy
746	746	17 credits" in an amount equal to its total energy output where a
747	747	18 renewable fuel is consumed or in an amount equal to the net
748	748	19 reduction in nonrenewable fuel consumed on a total energy
749	749	20 output basis.
750	750	21 "Real property" means any interest in land together with
751	751	22 all structures, fixtures, and improvements thereon, including
752	752	23 lands under water and riparian rights, any easements,
753	753	24 covenants, licenses, leases, rights-of-way, uses, and other
754	754	25 interests, together with any liens, judgments, mortgages, or
755	755	26 other claims or security interests related to real property.
756	756
757	757
758	758
759	759
760	760
761	761	HB5514 - 20 - LRB103 39335 CES 69496 b
762	762
763	763
764	764	HB5514- 21 -LRB103 39335 CES 69496 b HB5514 - 21 - LRB103 39335 CES 69496 b
765	765	HB5514 - 21 - LRB103 39335 CES 69496 b
766	766	1 "Renewable energy credit" means a tradable credit that
767	767	2 represents the environmental attributes of one megawatt hour
768	768	3 of energy produced from a renewable energy resource.
769	769	4 "Renewable energy resources" includes energy and its
770	770	5 associated renewable energy credit or renewable energy credits
771	771	6 from wind, solar thermal energy, photovoltaic cells and
772	772	7 panels, biodiesel, anaerobic digestion, crops and untreated
773	773	8 and unadulterated organic waste biomass, and hydropower that
774	774	9 does not involve new construction of dams, waste heat to power
775	775	10 systems, or qualified combined heat and power systems. For
776	776	11 purposes of this Act, landfill gas produced in the State is
777	777	12 considered a renewable energy resource. "Renewable energy
778	778	13 resources" does not include the incineration or burning of
779	779	14 tires, garbage, general household, institutional, and
780	780	15 commercial waste, industrial lunchroom or office waste,
781	781	16 landscape waste, railroad crossties, utility poles, or
782	782	17 construction or demolition debris, other than untreated and
783	783	18 unadulterated waste wood. "Renewable energy resources" also
784	784	19 includes high voltage direct current renewable energy credits
785	785	20 and the associated energy converted to alternating current by
786	786	21 a high voltage direct current converter station to the extent
787	787	22 that: (1) the generator of such renewable energy resource
788	788	23 contracted with a third party to transmit the energy over the
789	789	24 high voltage direct current transmission facilities, and (2)
790	790	25 the third-party contracting for delivery of renewable energy
791	791	26 resources over the high voltage direct current transmission
792	792
793	793
794	794
795	795
796	796
797	797	HB5514 - 21 - LRB103 39335 CES 69496 b
798	798
799	799
800	800	HB5514- 22 -LRB103 39335 CES 69496 b HB5514 - 22 - LRB103 39335 CES 69496 b
801	801	HB5514 - 22 - LRB103 39335 CES 69496 b
802	802	1 facilities have ownership rights over the unretired associated
803	803	2 high voltage direct current renewable energy credit.
804	804	3 "Retail customer" has the same definition as found in
805	805	4 Section 16-102 of the Public Utilities Act.
806	806	5 "Revenue bond" means any bond, note, or other evidence of
807	807	6 indebtedness issued by the Authority, the principal and
808	808	7 interest of which is payable solely from revenues or income
809	809	8 derived from any project or activity of the Agency.
810	810	9 "Sequester" means permanent storage of carbon dioxide by
811	811	10 injecting it into a saline aquifer, a depleted gas reservoir,
812	812	11 or an oil reservoir, directly or through an enhanced oil
813	813	12 recovery process that may involve intermediate storage,
814	814	13 regardless of whether these activities are conducted by a
815	815	14 clean coal facility, a clean coal SNG facility, a clean coal
816	816	15 SNG brownfield facility, or a party with which a clean coal
817	817	16 facility, clean coal SNG facility, or clean coal SNG
818	818	17 brownfield facility has contracted for such purposes.
819	819	18 "Service area" has the same definition as found in Section
820	820	19 16-102 of the Public Utilities Act.
821	821	20 "Settlement period" means the period of time utilized by
822	822	21 MISO and PJM and their successor organizations as the basis
823	823	22 for settlement calculations in the real-time energy market.
824	824	23 "Sourcing agreement" means (i) in the case of an electric
825	825	24 utility, an agreement between the owner of a clean coal
826	826	25 facility and such electric utility, which agreement shall have
827	827	26 terms and conditions meeting the requirements of paragraph (3)
828	828
829	829
830	830
831	831
832	832
833	833	HB5514 - 22 - LRB103 39335 CES 69496 b
834	834
835	835
836	836	HB5514- 23 -LRB103 39335 CES 69496 b HB5514 - 23 - LRB103 39335 CES 69496 b
837	837	HB5514 - 23 - LRB103 39335 CES 69496 b
838	838	1 of subsection (d) of Section 1-75, (ii) in the case of an
839	839	2 alternative retail electric supplier, an agreement between the
840	840	3 owner of a clean coal facility and such alternative retail
841	841	4 electric supplier, which agreement shall have terms and
842	842	5 conditions meeting the requirements of Section 16-115(d)(5) of
843	843	6 the Public Utilities Act, and (iii) in case of a gas utility,
844	844	7 an agreement between the owner of a clean coal SNG brownfield
845	845	8 facility and the gas utility, which agreement shall have the
846	846	9 terms and conditions meeting the requirements of subsection
847	847	10 (h-1) of Section 9-220 of the Public Utilities Act.
848	848	11 "Strike price" means a contract price for energy and
849	849	12 renewable energy credits from a new utility-scale wind project
850	850	13 or a new utility-scale photovoltaic project.
851	851	14 "Subscriber" means a person who (i) takes delivery service
852	852	15 from an electric utility, and (ii) has a subscription of no
853	853	16 less than 200 watts to a community renewable generation
854	854	17 project that is located in the electric utility's service
855	855	18 area. No subscriber's subscriptions may total more than 40% of
856	856	19 the nameplate capacity of an individual community renewable
857	857	20 generation project. Entities that are affiliated by virtue of
858	858	21 a common parent shall not represent multiple subscriptions
859	859	22 that total more than 40% of the nameplate capacity of an
860	860	23 individual community renewable generation project.
861	861	24 "Subscription" means an interest in a community renewable
862	862	25 generation project expressed in kilowatts, which is sized
863	863	26 primarily to offset part or all of the subscriber's
864	864
865	865
866	866
867	867
868	868
869	869	HB5514 - 23 - LRB103 39335 CES 69496 b
870	870
871	871
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873	873	HB5514 - 24 - LRB103 39335 CES 69496 b
874	874	1 electricity usage.
875	875	2 "Substitute natural gas" or "SNG" means a gas manufactured
876	876	3 by gasification of hydrocarbon feedstock, which is
877	877	4 substantially interchangeable in use and distribution with
878	878	5 conventional natural gas.
879	879	6 "Total resource cost test" or "TRC test" means a standard
880	880	7 that is met if, for an investment in energy efficiency or
881	881	8 demand-response measures, the benefit-cost ratio is greater
882	882	9 than one. The benefit-cost ratio is the ratio of the net
883	883	10 present value of the total benefits of the program to the net
884	884	11 present value of the total costs as calculated over the
885	885	12 lifetime of the measures. A total resource cost test compares
886	886	13 the sum of avoided electric utility costs, representing the
887	887	14 benefits that accrue to the system and the participant in the
888	888	15 delivery of those efficiency measures and including avoided
889	889	16 costs associated with reduced use of natural gas or other
890	890	17 fuels, avoided costs associated with reduced water
891	891	18 consumption, and avoided costs associated with reduced
892	892	19 operation and maintenance costs, as well as other quantifiable
893	893	20 societal benefits, to the sum of all incremental costs of
894	894	21 end-use measures that are implemented due to the program
895	895	22 (including both utility and participant contributions), plus
896	896	23 costs to administer, deliver, and evaluate each demand-side
897	897	24 program, to quantify the net savings obtained by substituting
898	898	25 the demand-side program for supply resources. In calculating
899	899	26 avoided costs of power and energy that an electric utility
900	900
901	901
902	902
903	903
904	904
905	905	HB5514 - 24 - LRB103 39335 CES 69496 b
906	906
907	907
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909	909	HB5514 - 25 - LRB103 39335 CES 69496 b
910	910	1 would otherwise have had to acquire, reasonable estimates
911	911	2 shall be included of financial costs likely to be imposed by
912	912	3 future regulations and legislation on emissions of greenhouse
913	913	4 gases. In discounting future societal costs and benefits for
914	914	5 the purpose of calculating net present values, a societal
915	915	6 discount rate based on actual, long-term Treasury bond yields
916	916	7 should be used. Notwithstanding anything to the contrary, the
917	917	8 TRC test shall not include or take into account a calculation
918	918	9 of market price suppression effects or demand reduction
919	919	10 induced price effects.
920	920	11 "Utility-scale solar project" means an electric generating
921	921	12 facility that:
922	922	13 (1) generates electricity using photovoltaic cells;
923	923	14 and
924	924	15 (2) has a nameplate capacity that is greater than
925	925	16 5,000 kilowatts.
926	926	17 "Utility-scale wind project" means an electric generating
927	927	18 facility that:
928	928	19 (1) generates electricity using wind; and
929	929	20 (2) has a nameplate capacity that is greater than
930	930	21 5,000 kilowatts.
931	931	22 "Waste Heat to Power Systems" means systems that capture
932	932	23 and generate electricity from energy that would otherwise be
933	933	24 lost to the atmosphere without the use of additional fuel.
934	934	25 "Zero emission credit" means a tradable credit that
935	935	26 represents the environmental attributes of one megawatt hour
936	936
937	937
938	938
939	939
940	940
941	941	HB5514 - 25 - LRB103 39335 CES 69496 b
942	942
943	943
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945	945	HB5514 - 26 - LRB103 39335 CES 69496 b
946	946	1 of energy produced from a zero emission facility.
947	947	2 "Zero emission facility" means a facility that: (1) is
948	948	3 fueled by nuclear power; and (2) is interconnected with PJM
949	949	4 Interconnection, LLC or the Midcontinent Independent System
950	950	5 Operator, Inc., or their successors.
951	951	6 (Source: P.A. 102-662, eff. 9-15-21; 103-154, eff. 6-28-23;
952	952	7 103-380, eff. 1-1-24.)
953	953	8 (20 ILCS 3855/1-20)
954	954	9 Sec. 1-20. General powers and duties of the Agency.
955	955	10 (a) The Agency is authorized to do each of the following:
956	956	11 (1) Develop electricity procurement plans to ensure
957	957	12 adequate, reliable, affordable, efficient, and
958	958	13 environmentally sustainable electric service at the lowest
959	959	14 total cost over time, taking into account any benefits of
960	960	15 price stability, for electric utilities that on December
961	961	16 31, 2005 provided electric service to at least 100,000
962	962	17 customers in Illinois and for small multi-jurisdictional
963	963	18 electric utilities that (A) on December 31, 2005 served
964	964	19 less than 100,000 customers in Illinois and (B) request a
965	965	20 procurement plan for their Illinois jurisdictional load.
966	966	21 Except as provided in paragraph (1.5) of this subsection
967	967	22 (a), the electricity procurement plans shall be updated on
968	968	23 an annual basis and shall include electricity generated
969	969	24 from renewable resources sufficient to achieve the
970	970	25 standards specified in this Act. Beginning with the
971	971
972	972
973	973
974	974
975	975
976	976	HB5514 - 26 - LRB103 39335 CES 69496 b
977	977
978	978
979	979	HB5514- 27 -LRB103 39335 CES 69496 b HB5514 - 27 - LRB103 39335 CES 69496 b
980	980	HB5514 - 27 - LRB103 39335 CES 69496 b
981	981	1 delivery year commencing June 1, 2017, develop procurement
982	982	2 plans to include zero emission credits generated from zero
983	983	3 emission facilities sufficient to achieve the standards
984	984	4 specified in this Act. Beginning with the delivery year
985	985	5 commencing on June 1, 2022, the Agency is authorized to
986	986	6 develop carbon mitigation credit procurement plans to
987	987	7 include carbon mitigation credits generated from
988	988	8 carbon-free energy resources sufficient to achieve the
989	989	9 standards specified in this Act.
990	990	10 (1.5) Develop a long-term renewable resources
991	991	11 procurement plan in accordance with subsection (c) of
992	992	12 Section 1-75 of this Act for renewable energy credits in
993	993	13 amounts sufficient to achieve the standards specified in
994	994	14 this Act for delivery years commencing June 1, 2017 and
995	995	15 for the programs and renewable energy credits specified in
996	996	16 Section 1-56 of this Act. Electricity procurement plans
997	997	17 for delivery years commencing after May 31, 2017, shall
998	998	18 not include procurement of renewable energy resources.
999	999	19 (1.7) Develop a high voltage direct current renewable
1000	1000	20 energy credit procurement in accordance with subsection
1001	1001	21 (c-7) of Section 1-75 of this Act for high voltage direct
1002	1002	22 current renewable energy credits for delivery starting on
1003	1003	23 or about June 1, 2029 or as otherwise provided in this Act
1004	1004	24 for at least 25 years, or as otherwise permitted under
1005	1005	25 that subsection.
1006	1006	26 (2) Conduct competitive procurement processes to
1007	1007
1008	1008
1009	1009
1010	1010
1011	1011
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1013	1013
1014	1014
1015	1015	HB5514- 28 -LRB103 39335 CES 69496 b HB5514 - 28 - LRB103 39335 CES 69496 b
1016	1016	HB5514 - 28 - LRB103 39335 CES 69496 b
1017	1017	1 procure the supply resources identified in the electricity
1018	1018	2 procurement plan, pursuant to Section 16-111.5 of the
1019	1019	3 Public Utilities Act, and, for the delivery year
1020	1020	4 commencing June 1, 2017, conduct procurement processes to
1021	1021	5 procure zero emission credits from zero emission
1022	1022	6 facilities, under subsection (d-5) of Section 1-75 of this
1023	1023	7 Act. For the delivery year commencing June 1, 2022, the
1024	1024	8 Agency is authorized to conduct procurement processes to
1025	1025	9 procure carbon mitigation credits from carbon-free energy
1026	1026	10 resources, under subsection (d-10) of Section 1-75 of this
1027	1027	11 Act.
1028	1028	12 (2.5) Beginning with the procurement for the 2017
1029	1029	13 delivery year, conduct competitive procurement processes
1030	1030	14 and implement programs to procure renewable energy credits
1031	1031	15 identified in the long-term renewable resources
1032	1032	16 procurement plan developed and approved under subsection
1033	1033	17 (c) of Section 1-75 of this Act and Section 16-111.5 of the
1034	1034	18 Public Utilities Act.
1035	1035	19 (2.10) Oversee the procurement by electric utilities
1036	1036	20 that served more than 300,000 customers in this State as
1037	1037	21 of January 1, 2019 of renewable energy credits from new
1038	1038	22 renewable energy facilities to be installed, along with
1039	1039	23 energy storage facilities, at or adjacent to the sites of
1040	1040	24 electric generating facilities that burned coal as their
1041	1041	25 primary fuel source as of January 1, 2016 in accordance
1042	1042	26 with subsection (c-5) of Section 1-75 of this Act.
1043	1043
1044	1044
1045	1045
1046	1046
1047	1047
1048	1048	HB5514 - 28 - LRB103 39335 CES 69496 b
1049	1049
1050	1050
1051	1051	HB5514- 29 -LRB103 39335 CES 69496 b HB5514 - 29 - LRB103 39335 CES 69496 b
1052	1052	HB5514 - 29 - LRB103 39335 CES 69496 b
1053	1053	1 (2.15) Oversee the procurement by electric utilities
1054	1054	2 of renewable energy credits from newly modernized or
1055	1055	3 retooled hydropower dams or dams that have been converted
1056	1056	4 to support hydropower generation.
1057	1057	5 (3) Develop electric generation and co-generation
1058	1058	6 facilities that use indigenous coal or renewable
1059	1059	7 resources, or both, financed with bonds issued by the
1060	1060	8 Illinois Finance Authority.
1061	1061	9 (4) Supply electricity from the Agency's facilities at
1062	1062	10 cost to one or more of the following: municipal electric
1063	1063	11 systems, governmental aggregators, or rural electric
1064	1064	12 cooperatives in Illinois.
1065	1065	13 (b) Except as otherwise limited by this Act, the Agency
1066	1066	14 has all of the powers necessary or convenient to carry out the
1067	1067	15 purposes and provisions of this Act, including without
1068	1068	16 limitation, each of the following:
1069	1069	17 (1) To have a corporate seal, and to alter that seal at
1070	1070	18 pleasure, and to use it by causing it or a facsimile to be
1071	1071	19 affixed or impressed or reproduced in any other manner.
1072	1072	20 (2) To use the services of the Illinois Finance
1073	1073	21 Authority necessary to carry out the Agency's purposes.
1074	1074	22 (3) To negotiate and enter into loan agreements and
1075	1075	23 other agreements with the Illinois Finance Authority.
1076	1076	24 (4) To obtain and employ personnel and hire
1077	1077	25 consultants that are necessary to fulfill the Agency's
1078	1078	26 purposes, and to make expenditures for that purpose within
1079	1079
1080	1080
1081	1081
1082	1082
1083	1083
1084	1084	HB5514 - 29 - LRB103 39335 CES 69496 b
1085	1085
1086	1086
1087	1087	HB5514- 30 -LRB103 39335 CES 69496 b HB5514 - 30 - LRB103 39335 CES 69496 b
1088	1088	HB5514 - 30 - LRB103 39335 CES 69496 b
1089	1089	1 the appropriations for that purpose.
1090	1090	2 (5) To purchase, receive, take by grant, gift, devise,
1091	1091	3 bequest, or otherwise, lease, or otherwise acquire, own,
1092	1092	4 hold, improve, employ, use, and otherwise deal in and
1093	1093	5 with, real or personal property whether tangible or
1094	1094	6 intangible, or any interest therein, within the State.
1095	1095	7 (6) To acquire real or personal property, whether
1096	1096	8 tangible or intangible, including without limitation
1097	1097	9 property rights, interests in property, franchises,
1098	1098	10 obligations, contracts, and debt and equity securities,
1099	1099	11 and to do so by the exercise of the power of eminent domain
1100	1100	12 in accordance with Section 1-21; except that any real
1101	1101	13 property acquired by the exercise of the power of eminent
1102	1102	14 domain must be located within the State.
1103	1103	15 (7) To sell, convey, lease, exchange, transfer,
1104	1104	16 abandon, or otherwise dispose of, or mortgage, pledge, or
1105	1105	17 create a security interest in, any of its assets,
1106	1106	18 properties, or any interest therein, wherever situated.
1107	1107	19 (8) To purchase, take, receive, subscribe for, or
1108	1108	20 otherwise acquire, hold, make a tender offer for, vote,
1109	1109	21 employ, sell, lend, lease, exchange, transfer, or
1110	1110	22 otherwise dispose of, mortgage, pledge, or grant a
1111	1111	23 security interest in, use, and otherwise deal in and with,
1112	1112	24 bonds and other obligations, shares, or other securities
1113	1113	25 (or interests therein) issued by others, whether engaged
1114	1114	26 in a similar or different business or activity.
1115	1115
1116	1116
1117	1117
1118	1118
1119	1119
1120	1120	HB5514 - 30 - LRB103 39335 CES 69496 b
1121	1121
1122	1122
1123	1123	HB5514- 31 -LRB103 39335 CES 69496 b HB5514 - 31 - LRB103 39335 CES 69496 b
1124	1124	HB5514 - 31 - LRB103 39335 CES 69496 b
1125	1125	1 (9) To make and execute agreements, contracts, and
1126	1126	2 other instruments necessary or convenient in the exercise
1127	1127	3 of the powers and functions of the Agency under this Act,
1128	1128	4 including contracts with any person, including personal
1129	1129	5 service contracts, or with any local government, State
1130	1130	6 agency, or other entity; and all State agencies and all
1131	1131	7 local governments are authorized to enter into and do all
1132	1132	8 things necessary to perform any such agreement, contract,
1133	1133	9 or other instrument with the Agency. No such agreement,
1134	1134	10 contract, or other instrument shall exceed 40 years.
1135	1135	11 (10) To lend money, invest and reinvest its funds in
1136	1136	12 accordance with the Public Funds Investment Act, and take
1137	1137	13 and hold real and personal property as security for the
1138	1138	14 payment of funds loaned or invested.
1139	1139	15 (11) To borrow money at such rate or rates of interest
1140	1140	16 as the Agency may determine, issue its notes, bonds, or
1141	1141	17 other obligations to evidence that indebtedness, and
1142	1142	18 secure any of its obligations by mortgage or pledge of its
1143	1143	19 real or personal property, machinery, equipment,
1144	1144	20 structures, fixtures, inventories, revenues, grants, and
1145	1145	21 other funds as provided or any interest therein, wherever
1146	1146	22 situated.
1147	1147	23 (12) To enter into agreements with the Illinois
1148	1148	24 Finance Authority to issue bonds whether or not the income
1149	1149	25 therefrom is exempt from federal taxation.
1150	1150	26 (13) To procure insurance against any loss in
1151	1151
1152	1152
1153	1153
1154	1154
1155	1155
1156	1156	HB5514 - 31 - LRB103 39335 CES 69496 b
1157	1157
1158	1158
1159	1159	HB5514- 32 -LRB103 39335 CES 69496 b HB5514 - 32 - LRB103 39335 CES 69496 b
1160	1160	HB5514 - 32 - LRB103 39335 CES 69496 b
1161	1161	1 connection with its properties or operations in such
1162	1162	2 amount or amounts and from such insurers, including the
1163	1163	3 federal government, as it may deem necessary or desirable,
1164	1164	4 and to pay any premiums therefor.
1165	1165	5 (14) To negotiate and enter into agreements with
1166	1166	6 trustees or receivers appointed by United States
1167	1167	7 bankruptcy courts or federal district courts or in other
1168	1168	8 proceedings involving adjustment of debts and authorize
1169	1169	9 proceedings involving adjustment of debts and authorize
1170	1170	10 legal counsel for the Agency to appear in any such
1171	1171	11 proceedings.
1172	1172	12 (15) To file a petition under Chapter 9 of Title 11 of
1173	1173	13 the United States Bankruptcy Code or take other similar
1174	1174	14 action for the adjustment of its debts.
1175	1175	15 (16) To enter into management agreements for the
1176	1176	16 operation of any of the property or facilities owned by
1177	1177	17 the Agency.
1178	1178	18 (17) To enter into an agreement to transfer and to
1179	1179	19 transfer any land, facilities, fixtures, or equipment of
1180	1180	20 the Agency to one or more municipal electric systems,
1181	1181	21 governmental aggregators, or rural electric agencies or
1182	1182	22 cooperatives, for such consideration and upon such terms
1183	1183	23 as the Agency may determine to be in the best interest of
1184	1184	24 the residents of Illinois.
1185	1185	25 (18) To enter upon any lands and within any building
1186	1186	26 whenever in its judgment it may be necessary for the
1187	1187
1188	1188
1189	1189
1190	1190
1191	1191
1192	1192	HB5514 - 32 - LRB103 39335 CES 69496 b
1193	1193
1194	1194
1195	1195	HB5514- 33 -LRB103 39335 CES 69496 b HB5514 - 33 - LRB103 39335 CES 69496 b
1196	1196	HB5514 - 33 - LRB103 39335 CES 69496 b
1197	1197	1 purpose of making surveys and examinations to accomplish
1198	1198	2 any purpose authorized by this Act.
1199	1199	3 (19) To maintain an office or offices at such place or
1200	1200	4 places in the State as it may determine.
1201	1201	5 (20) To request information, and to make any inquiry,
1202	1202	6 investigation, survey, or study that the Agency may deem
1203	1203	7 necessary to enable it effectively to carry out the
1204	1204	8 provisions of this Act.
1205	1205	9 (21) To accept and expend appropriations.
1206	1206	10 (22) To engage in any activity or operation that is
1207	1207	11 incidental to and in furtherance of efficient operation to
1208	1208	12 accomplish the Agency's purposes, including hiring
1209	1209	13 employees that the Director deems essential for the
1210	1210	14 operations of the Agency.
1211	1211	15 (23) To adopt, revise, amend, and repeal rules with
1212	1212	16 respect to its operations, properties, and facilities as
1213	1213	17 may be necessary or convenient to carry out the purposes
1214	1214	18 of this Act, subject to the provisions of the Illinois
1215	1215	19 Administrative Procedure Act and Sections 1-22 and 1-35 of
1216	1216	20 this Act.
1217	1217	21 (24) To establish and collect charges and fees as
1218	1218	22 described in this Act.
1219	1219	23 (25) To conduct competitive gasification feedstock
1220	1220	24 procurement processes to procure the feedstocks for the
1221	1221	25 clean coal SNG brownfield facility in accordance with the
1222	1222	26 requirements of Section 1-78 of this Act.
1223	1223
1224	1224
1225	1225
1226	1226
1227	1227
1228	1228	HB5514 - 33 - LRB103 39335 CES 69496 b
1229	1229
1230	1230
1231	1231	HB5514- 34 -LRB103 39335 CES 69496 b HB5514 - 34 - LRB103 39335 CES 69496 b
1232	1232	HB5514 - 34 - LRB103 39335 CES 69496 b
1233	1233	1 (26) To review, revise, and approve sourcing
1234	1234	2 agreements and mediate and resolve disputes between gas
1235	1235	3 utilities and the clean coal SNG brownfield facility
1236	1236	4 pursuant to subsection (h-1) of Section 9-220 of the
1237	1237	5 Public Utilities Act.
1238	1238	6 (27) To request, review and accept proposals, execute
1239	1239	7 contracts, purchase renewable energy credits and otherwise
1240	1240	8 dedicate funds from the Illinois Power Agency Renewable
1241	1241	9 Energy Resources Fund to create and carry out the
1242	1242	10 objectives of the Illinois Solar for All Program in
1243	1243	11 accordance with Section 1-56 of this Act.
1244	1244	12 (28) To ensure Illinois residents and business benefit
1245	1245	13 from programs administered by the Agency and are properly
1246	1246	14 protected from any deceptive or misleading marketing
1247	1247	15 practices by participants in the Agency's programs and
1248	1248	16 procurements.
1249	1249	17 (c) In conducting the procurement of electricity or other
1250	1250	18 products, beginning January 1, 2022, the Agency shall not
1251	1251	19 procure any products or services from persons or organizations
1252	1252	20 that are in violation of the Displaced Energy Workers Bill of
1253	1253	21 Rights, as provided under the Energy Community Reinvestment
1254	1254	22 Act at the time of the procurement event or fail to comply the
1255	1255	23 labor standards established in subparagraph (Q) of paragraph
1256	1256	24 (1) of subsection (c) of Section 1-75.
1257	1257	25 (Source: P.A. 102-662, eff. 9-15-21; 103-380, eff. 1-1-24.)
1258	1258
1259	1259
1260	1260
1261	1261
1262	1262
1263	1263	HB5514 - 34 - LRB103 39335 CES 69496 b
1264	1264
1265	1265
1266	1266	HB5514- 35 -LRB103 39335 CES 69496 b HB5514 - 35 - LRB103 39335 CES 69496 b
1267	1267	HB5514 - 35 - LRB103 39335 CES 69496 b
1268	1268	1 (20 ILCS 3855/1-75)
1269	1269	2 Sec. 1-75. Planning and Procurement Bureau. The Planning
1270	1270	3 and Procurement Bureau has the following duties and
1271	1271	4 responsibilities:
1272	1272	5 (a) The Planning and Procurement Bureau shall each year,
1273	1273	6 beginning in 2008, develop procurement plans and conduct
1274	1274	7 competitive procurement processes in accordance with the
1275	1275	8 requirements of Section 16-111.5 of the Public Utilities Act
1276	1276	9 for the eligible retail customers of electric utilities that
1277	1277	10 on December 31, 2005 provided electric service to at least
1278	1278	11 100,000 customers in Illinois. Beginning with the delivery
1279	1279	12 year commencing on June 1, 2017, the Planning and Procurement
1280	1280	13 Bureau shall develop plans and processes for the procurement
1281	1281	14 of zero emission credits from zero emission facilities in
1282	1282	15 accordance with the requirements of subsection (d-5) of this
1283	1283	16 Section. Beginning on the effective date of this amendatory
1284	1284	17 Act of the 102nd General Assembly, the Planning and
1285	1285	18 Procurement Bureau shall develop plans and processes for the
1286	1286	19 procurement of carbon mitigation credits from carbon-free
1287	1287	20 energy resources in accordance with the requirements of
1288	1288	21 subsection (d-10) of this Section. The Planning and
1289	1289	22 Procurement Bureau shall also develop procurement plans and
1290	1290	23 conduct competitive procurement processes in accordance with
1291	1291	24 the requirements of Section 16-111.5 of the Public Utilities
1292	1292	25 Act for the eligible retail customers of small
1293	1293	26 multi-jurisdictional electric utilities that (i) on December
1294	1294
1295	1295
1296	1296
1297	1297
1298	1298
1299	1299	HB5514 - 35 - LRB103 39335 CES 69496 b
1300	1300
1301	1301
1302	1302	HB5514- 36 -LRB103 39335 CES 69496 b HB5514 - 36 - LRB103 39335 CES 69496 b
1303	1303	HB5514 - 36 - LRB103 39335 CES 69496 b
1304	1304	1 31, 2005 served less than 100,000 customers in Illinois and
1305	1305	2 (ii) request a procurement plan for their Illinois
1306	1306	3 jurisdictional load. This Section shall not apply to a small
1307	1307	4 multi-jurisdictional utility until such time as a small
1308	1308	5 multi-jurisdictional utility requests the Agency to prepare a
1309	1309	6 procurement plan for their Illinois jurisdictional load. For
1310	1310	7 the purposes of this Section, the term "eligible retail
1311	1311	8 customers" has the same definition as found in Section
1312	1312	9 16-111.5(a) of the Public Utilities Act.
1313	1313	10 Beginning with the plan or plans to be implemented in the
1314	1314	11 2017 delivery year, the Agency shall no longer include the
1315	1315	12 procurement of renewable energy resources in the annual
1316	1316	13 procurement plans required by this subsection (a), except as
1317	1317	14 provided in subsection (q) of Section 16-111.5 of the Public
1318	1318	15 Utilities Act, and shall instead develop a long-term renewable
1319	1319	16 resources procurement plan in accordance with subsection (c)
1320	1320	17 of this Section and Section 16-111.5 of the Public Utilities
1321	1321	18 Act.
1322	1322	19 In accordance with subsection (c-5) of this Section, the
1323	1323	20 Planning and Procurement Bureau shall oversee the procurement
1324	1324	21 by electric utilities that served more than 300,000 retail
1325	1325	22 customers in this State as of January 1, 2019 of renewable
1326	1326	23 energy credits from new utility-scale solar projects to be
1327	1327	24 installed, along with energy storage facilities, at or
1328	1328	25 adjacent to the sites of electric generating facilities that,
1329	1329	26 as of January 1, 2016, burned coal as their primary fuel
1330	1330
1331	1331
1332	1332
1333	1333
1334	1334
1335	1335	HB5514 - 36 - LRB103 39335 CES 69496 b
1336	1336
1337	1337
1338	1338	HB5514- 37 -LRB103 39335 CES 69496 b HB5514 - 37 - LRB103 39335 CES 69496 b
1339	1339	HB5514 - 37 - LRB103 39335 CES 69496 b
1340	1340	1 source.
1341	1341	2 In accordance with subsection (c-7) of this Section, the
1342	1342	3 Planning and Procurement Bureau shall oversee the procurement
1343	1343	4 by electric utilities that served more than 300,000 retail
1344	1344	5 customers in this State as of January 1, 2019 of high voltage
1345	1345	6 direct current renewable energy credits.
1346	1346	7 (1) The Agency shall each year, beginning in 2008, as
1347	1347	8 needed, issue a request for qualifications for experts or
1348	1348	9 expert consulting firms to develop the procurement plans
1349	1349	10 in accordance with Section 16-111.5 of the Public
1350	1350	11 Utilities Act. In order to qualify an expert or expert
1351	1351	12 consulting firm must have:
1352	1352	13 (A) direct previous experience assembling
1353	1353	14 large-scale power supply plans or portfolios for
1354	1354	15 end-use customers;
1355	1355	16 (B) an advanced degree in economics, mathematics,
1356	1356	17 engineering, risk management, or a related area of
1357	1357	18 study;
1358	1358	19 (C) 10 years of experience in the electricity
1359	1359	20 sector, including managing supply risk;
1360	1360	21 (D) expertise in wholesale electricity market
1361	1361	22 rules, including those established by the Federal
1362	1362	23 Energy Regulatory Commission and regional transmission
1363	1363	24 organizations;
1364	1364	25 (E) expertise in credit protocols and familiarity
1365	1365	26 with contract protocols;
1366	1366
1367	1367
1368	1368
1369	1369
1370	1370
1371	1371	HB5514 - 37 - LRB103 39335 CES 69496 b
1372	1372
1373	1373
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1375	1375	HB5514 - 38 - LRB103 39335 CES 69496 b
1376	1376	1 (F) adequate resources to perform and fulfill the
1377	1377	2 required functions and responsibilities; and
1378	1378	3 (G) the absence of a conflict of interest and
1379	1379	4 inappropriate bias for or against potential bidders or
1380	1380	5 the affected electric utilities.
1381	1381	6 (2) The Agency shall each year, as needed, issue a
1382	1382	7 request for qualifications for a procurement administrator
1383	1383	8 to conduct the competitive procurement processes in
1384	1384	9 accordance with Section 16-111.5 of the Public Utilities
1385	1385	10 Act. In order to qualify an expert or expert consulting
1386	1386	11 firm must have:
1387	1387	12 (A) direct previous experience administering a
1388	1388	13 large-scale competitive procurement process;
1389	1389	14 (B) an advanced degree in economics, mathematics,
1390	1390	15 engineering, or a related area of study;
1391	1391	16 (C) 10 years of experience in the electricity
1392	1392	17 sector, including risk management experience;
1393	1393	18 (D) expertise in wholesale electricity market
1394	1394	19 rules, including those established by the Federal
1395	1395	20 Energy Regulatory Commission and regional transmission
1396	1396	21 organizations;
1397	1397	22 (E) expertise in credit and contract protocols;
1398	1398	23 (F) adequate resources to perform and fulfill the
1399	1399	24 required functions and responsibilities; and
1400	1400	25 (G) the absence of a conflict of interest and
1401	1401	26 inappropriate bias for or against potential bidders or
1402	1402
1403	1403
1404	1404
1405	1405
1406	1406
1407	1407	HB5514 - 38 - LRB103 39335 CES 69496 b
1408	1408
1409	1409
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1411	1411	HB5514 - 39 - LRB103 39335 CES 69496 b
1412	1412	1 the affected electric utilities.
1413	1413	2 (3) The Agency shall provide affected utilities and
1414	1414	3 other interested parties with the lists of qualified
1415	1415	4 experts or expert consulting firms identified through the
1416	1416	5 request for qualifications processes that are under
1417	1417	6 consideration to develop the procurement plans and to
1418	1418	7 serve as the procurement administrator. The Agency shall
1419	1419	8 also provide each qualified expert's or expert consulting
1420	1420	9 firm's response to the request for qualifications. All
1421	1421	10 information provided under this subparagraph shall also be
1422	1422	11 provided to the Commission. The Agency may provide by rule
1423	1423	12 for fees associated with supplying the information to
1424	1424	13 utilities and other interested parties. These parties
1425	1425	14 shall, within 5 business days, notify the Agency in
1426	1426	15 writing if they object to any experts or expert consulting
1427	1427	16 firms on the lists. Objections shall be based on:
1428	1428	17 (A) failure to satisfy qualification criteria;
1429	1429	18 (B) identification of a conflict of interest; or
1430	1430	19 (C) evidence of inappropriate bias for or against
1431	1431	20 potential bidders or the affected utilities.
1432	1432	21 The Agency shall remove experts or expert consulting
1433	1433	22 firms from the lists within 10 days if there is a
1434	1434	23 reasonable basis for an objection and provide the updated
1435	1435	24 lists to the affected utilities and other interested
1436	1436	25 parties. If the Agency fails to remove an expert or expert
1437	1437	26 consulting firm from a list, an objecting party may seek
1438	1438
1439	1439
1440	1440
1441	1441
1442	1442
1443	1443	HB5514 - 39 - LRB103 39335 CES 69496 b
1444	1444
1445	1445
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1447	1447	HB5514 - 40 - LRB103 39335 CES 69496 b
1448	1448	1 review by the Commission within 5 days thereafter by
1449	1449	2 filing a petition, and the Commission shall render a
1450	1450	3 ruling on the petition within 10 days. There is no right of
1451	1451	4 appeal of the Commission's ruling.
1452	1452	5 (4) The Agency shall issue requests for proposals to
1453	1453	6 the qualified experts or expert consulting firms to
1454	1454	7 develop a procurement plan for the affected utilities and
1455	1455	8 to serve as procurement administrator.
1456	1456	9 (5) The Agency shall select an expert or expert
1457	1457	10 consulting firm to develop procurement plans based on the
1458	1458	11 proposals submitted and shall award contracts of up to 5
1459	1459	12 years to those selected.
1460	1460	13 (6) The Agency shall select an expert or expert
1461	1461	14 consulting firm, with approval of the Commission, to serve
1462	1462	15 as procurement administrator based on the proposals
1463	1463	16 submitted. If the Commission rejects, within 5 days, the
1464	1464	17 Agency's selection, the Agency shall submit another
1465	1465	18 recommendation within 3 days based on the proposals
1466	1466	19 submitted. The Agency shall award a 5-year contract to the
1467	1467	20 expert or expert consulting firm so selected with
1468	1468	21 Commission approval.
1469	1469	22 (b) The experts or expert consulting firms retained by the
1470	1470	23 Agency shall, as appropriate, prepare procurement plans, and
1471	1471	24 conduct a competitive procurement process as prescribed in
1472	1472	25 Section 16-111.5 of the Public Utilities Act, to ensure
1473	1473	26 adequate, reliable, affordable, efficient, and environmentally
1474	1474
1475	1475
1476	1476
1477	1477
1478	1478
1479	1479	HB5514 - 40 - LRB103 39335 CES 69496 b
1480	1480
1481	1481
1482	1482	HB5514- 41 -LRB103 39335 CES 69496 b HB5514 - 41 - LRB103 39335 CES 69496 b
1483	1483	HB5514 - 41 - LRB103 39335 CES 69496 b
1484	1484	1 sustainable electric service at the lowest total cost over
1485	1485	2 time, taking into account any benefits of price stability, for
1486	1486	3 eligible retail customers of electric utilities that on
1487	1487	4 December 31, 2005 provided electric service to at least
1488	1488	5 100,000 customers in the State of Illinois, and for eligible
1489	1489	6 Illinois retail customers of small multi-jurisdictional
1490	1490	7 electric utilities that (i) on December 31, 2005 served less
1491	1491	8 than 100,000 customers in Illinois and (ii) request a
1492	1492	9 procurement plan for their Illinois jurisdictional load.
1493	1493	10 (c) Renewable portfolio standard.
1494	1494	11 (1)(A) The Agency shall develop a long-term renewable
1495	1495	12 resources procurement plan that shall include procurement
1496	1496	13 programs and competitive procurement events necessary to
1497	1497	14 meet the goals set forth in this subsection (c). The
1498	1498	15 initial long-term renewable resources procurement plan
1499	1499	16 shall be released for comment no later than 160 days after
1500	1500	17 June 1, 2017 (the effective date of Public Act 99-906).
1501	1501	18 The Agency shall review, and may revise on an expedited
1502	1502	19 basis, the long-term renewable resources procurement plan
1503	1503	20 at least every 2 years, which shall be conducted in
1504	1504	21 conjunction with the procurement plan under Section
1505	1505	22 16-111.5 of the Public Utilities Act to the extent
1506	1506	23 practicable to minimize administrative expense. No later
1507	1507	24 than 120 days after the effective date of this amendatory
1508	1508	25 Act of the 103rd General Assembly, the Agency shall
1509	1509	26 release for comment a revision to the long-term renewable
1510	1510
1511	1511
1512	1512
1513	1513
1514	1514
1515	1515	HB5514 - 41 - LRB103 39335 CES 69496 b
1516	1516
1517	1517
1518	1518	HB5514- 42 -LRB103 39335 CES 69496 b HB5514 - 42 - LRB103 39335 CES 69496 b
1519	1519	HB5514 - 42 - LRB103 39335 CES 69496 b
1520	1520	1 resources procurement plan, updating elements of the most
1521	1521	2 recently approved plan as needed to comply with this
1522	1522	3 amendatory Act of the 103rd General Assembly, and any
1523	1523	4 long-term renewable resources procurement plan update
1524	1524	5 published by the Agency but not yet approved by the
1525	1525	6 Illinois Commerce Commission shall be withdrawn. The
1526	1526	7 long-term renewable resources procurement plans shall be
1527	1527	8 subject to review and approval by the Commission under
1528	1528	9 Section 16-111.5 of the Public Utilities Act.
1529	1529	10 (B) Subject to subparagraph (F) of this paragraph (1),
1530	1530	11 the long-term renewable resources procurement plan shall
1531	1531	12 attempt to meet the goals for procurement of renewable
1532	1532	13 energy credits at levels of at least the following overall
1533	1533	14 percentages: 13% by the 2017 delivery year; increasing by
1534	1534	15 at least 1.5% each delivery year thereafter to at least
1535	1535	16 25% by the 2025 delivery year; increasing by at least 3%
1536	1536	17 each delivery year thereafter to at least 40% by the 2030
1537	1537	18 delivery year, and continuing at no less than 40% for each
1538	1538	19 delivery year thereafter. The Agency shall attempt to
1539	1539	20 procure 50% by delivery year 2040. The Agency shall
1540	1540	21 determine the annual increase between delivery year 2030
1541	1541	22 and delivery year 2040, if any, taking into account energy
1542	1542	23 demand, other energy resources, and other public policy
1543	1543	24 goals. In the event of a conflict between these goals and
1544	1544	25 the new wind, new photovoltaic, and hydropower procurement
1545	1545	26 requirements described in items (i) through (iii) of
1546	1546
1547	1547
1548	1548
1549	1549
1550	1550
1551	1551	HB5514 - 42 - LRB103 39335 CES 69496 b
1552	1552
1553	1553
1554	1554	HB5514- 43 -LRB103 39335 CES 69496 b HB5514 - 43 - LRB103 39335 CES 69496 b
1555	1555	HB5514 - 43 - LRB103 39335 CES 69496 b
1556	1556	1 subparagraph (C) of this paragraph (1), the long-term plan
1557	1557	2 shall prioritize compliance with the new wind, new
1558	1558	3 photovoltaic, and hydropower procurement requirements
1559	1559	4 described in items (i) through (iii) of subparagraph (C)
1560	1560	5 of this paragraph (1) over the annual percentage targets
1561	1561	6 described in this subparagraph (B). The Agency shall not
1562	1562	7 comply with the annual percentage targets described in
1563	1563	8 this subparagraph (B) by procuring renewable energy
1564	1564	9 credits that are unlikely to lead to the development of
1565	1565	10 new renewable resources or new, modernized, or retooled
1566	1566	11 hydropower facilities.
1567	1567	12 For the delivery year beginning June 1, 2017, the
1568	1568	13 procurement plan shall attempt to include, subject to the
1569	1569	14 prioritization outlined in this subparagraph (B),
1570	1570	15 cost-effective renewable energy resources equal to at
1571	1571	16 least 13% of each utility's load for eligible retail
1572	1572	17 customers and 13% of the applicable portion of each
1573	1573	18 utility's load for retail customers who are not eligible
1574	1574	19 retail customers, which applicable portion shall equal 50%
1575	1575	20 of the utility's load for retail customers who are not
1576	1576	21 eligible retail customers on February 28, 2017.
1577	1577	22 For the delivery year beginning June 1, 2018, the
1578	1578	23 procurement plan shall attempt to include, subject to the
1579	1579	24 prioritization outlined in this subparagraph (B),
1580	1580	25 cost-effective renewable energy resources equal to at
1581	1581	26 least 14.5% of each utility's load for eligible retail
1582	1582
1583	1583
1584	1584
1585	1585
1586	1586
1587	1587	HB5514 - 43 - LRB103 39335 CES 69496 b
1588	1588
1589	1589
1590	1590	HB5514- 44 -LRB103 39335 CES 69496 b HB5514 - 44 - LRB103 39335 CES 69496 b
1591	1591	HB5514 - 44 - LRB103 39335 CES 69496 b
1592	1592	1 customers and 14.5% of the applicable portion of each
1593	1593	2 utility's load for retail customers who are not eligible
1594	1594	3 retail customers, which applicable portion shall equal 75%
1595	1595	4 of the utility's load for retail customers who are not
1596	1596	5 eligible retail customers on February 28, 2017.
1597	1597	6 For the delivery year beginning June 1, 2019, and for
1598	1598	7 each year thereafter, the procurement plans shall attempt
1599	1599	8 to include, subject to the prioritization outlined in this
1600	1600	9 subparagraph (B), cost-effective renewable energy
1601	1601	10 resources equal to a minimum percentage of each utility's
1602	1602	11 load for all retail customers as follows: 16% by June 1,
1603	1603	12 2019; increasing by 1.5% each year thereafter to 25% by
1604	1604	13 June 1, 2025; and 25% by June 1, 2026; increasing by at
1605	1605	14 least 3% each delivery year thereafter to at least 40% by
1606	1606	15 the 2030 delivery year, and continuing at no less than 40%
1607	1607	16 for each delivery year thereafter. The Agency shall
1608	1608	17 attempt to procure 50% by delivery year 2040. The Agency
1609	1609	18 shall determine the annual increase between delivery year
1610	1610	19 2030 and delivery year 2040, if any, taking into account
1611	1611	20 energy demand, other energy resources, and other public
1612	1612	21 policy goals.
1613	1613	22 For each delivery year, the Agency shall first
1614	1614	23 recognize each utility's obligations for that delivery
1615	1615	24 year under existing contracts. Any renewable energy
1616	1616	25 credits under existing contracts, including renewable
1617	1617	26 energy credits as part of renewable energy resources,
1618	1618
1619	1619
1620	1620
1621	1621
1622	1622
1623	1623	HB5514 - 44 - LRB103 39335 CES 69496 b
1624	1624
1625	1625
1626	1626	HB5514- 45 -LRB103 39335 CES 69496 b HB5514 - 45 - LRB103 39335 CES 69496 b
1627	1627	HB5514 - 45 - LRB103 39335 CES 69496 b
1628	1628	1 shall be used to meet the goals set forth in this
1629	1629	2 subsection (c) for the delivery year.
1630	1630	3 (C) The long-term renewable resources procurement plan
1631	1631	4 described in subparagraph (A) of this paragraph (1) shall
1632	1632	5 include the procurement of renewable energy credits from
1633	1633	6 new projects pursuant to the following terms:
1634	1634	7 (i) At least 10,000,000 renewable energy credits
1635	1635	8 delivered annually by the end of the 2021 delivery
1636	1636	9 year, and increasing ratably to reach 45,000,000
1637	1637	10 renewable energy credits delivered annually from new
1638	1638	11 wind and solar projects by the end of delivery year
1639	1639	12 2030 such that the goals in subparagraph (B) of this
1640	1640	13 paragraph (1) are met entirely by procurements of
1641	1641	14 renewable energy credits from new wind and
1642	1642	15 photovoltaic projects. Of that amount, to the extent
1643	1643	16 possible, the Agency shall procure 45% from wind and
1644	1644	17 hydropower projects and 55% from photovoltaic
1645	1645	18 projects. Of the amount to be procured from
1646	1646	19 photovoltaic projects, the Agency shall procure: at
1647	1647	20 least 50% from solar photovoltaic projects using the
1648	1648	21 program outlined in subparagraph (K) of this paragraph
1649	1649	22 (1) from distributed renewable energy generation
1650	1650	23 devices or community renewable generation projects; at
1651	1651	24 least 47% from utility-scale solar projects; at least
1652	1652	25 3% from brownfield site photovoltaic projects that are
1653	1653	26 not community renewable generation projects. High
1654	1654
1655	1655
1656	1656
1657	1657
1658	1658
1659	1659	HB5514 - 45 - LRB103 39335 CES 69496 b
1660	1660
1661	1661
1662	1662	HB5514- 46 -LRB103 39335 CES 69496 b HB5514 - 46 - LRB103 39335 CES 69496 b
1663	1663	HB5514 - 46 - LRB103 39335 CES 69496 b
1664	1664	1 voltage direct current renewable energy credits
1665	1665	2 procured by the Agency pursuant to subsection (c-7) of
1666	1666	3 this Section 1-75 shall not count toward the renewable
1667	1667	4 energy credit purchase targets in this subparagraph
1668	1668	5 (i); however, nothing prohibits the Agency from
1669	1669	6 procuring high voltage direct current renewable energy
1670	1670	7 credits under a procurement authorized by this
1671	1671	8 subsection (c) from counting toward the renewable
1672	1672	9 energy credit purchase targets in this subparagraph
1673	1673	10 (i).
1674	1674	11 In developing the long-term renewable resources
1675	1675	12 procurement plan, the Agency shall consider other
1676	1676	13 approaches, in addition to competitive procurements,
1677	1677	14 that can be used to procure renewable energy credits
1678	1678	15 from brownfield site photovoltaic projects and thereby
1679	1679	16 help return blighted or contaminated land to
1680	1680	17 productive use while enhancing public health and the
1681	1681	18 well-being of Illinois residents, including those in
1682	1682	19 environmental justice communities, as defined using
1683	1683	20 existing methodologies and findings used by the Agency
1684	1684	21 and its Administrator in its Illinois Solar for All
1685	1685	22 Program. The Agency shall also consider other
1686	1686	23 approaches, in addition to competitive procurements,
1687	1687	24 to procure renewable energy credits from new and
1688	1688	25 existing hydropower facilities to support the
1689	1689	26 development and maintenance of these facilities. The
1690	1690
1691	1691
1692	1692
1693	1693
1694	1694
1695	1695	HB5514 - 46 - LRB103 39335 CES 69496 b
1696	1696
1697	1697
1698	1698	HB5514- 47 -LRB103 39335 CES 69496 b HB5514 - 47 - LRB103 39335 CES 69496 b
1699	1699	HB5514 - 47 - LRB103 39335 CES 69496 b
1700	1700	1 Agency shall explore options to convert existing dams
1701	1701	2 but shall not consider approaches to develop new dams
1702	1702	3 where they do not already exist.
1703	1703	4 (ii) In any given delivery year, if forecasted
1704	1704	5 expenses are less than the maximum budget available
1705	1705	6 under subparagraph (E) of this paragraph (1), the
1706	1706	7 Agency shall continue to procure new renewable energy
1707	1707	8 credits until that budget is exhausted in the manner
1708	1708	9 outlined in item (i) of this subparagraph (C).
1709	1709	10 (iii) For purposes of this Section:
1710	1710	11 "New wind projects" means wind renewable energy
1711	1711	12 facilities that are energized after June 1, 2017 for
1712	1712	13 the delivery year commencing June 1, 2017.
1713	1713	14 "New photovoltaic projects" means photovoltaic
1714	1714	15 renewable energy facilities that are energized after
1715	1715	16 June 1, 2017. Photovoltaic projects developed under
1716	1716	17 Section 1-56 of this Act shall not apply towards the
1717	1717	18 new photovoltaic project requirements in this
1718	1718	19 subparagraph (C).
1719	1719	20 For purposes of calculating whether the Agency has
1720	1720	21 procured enough new wind and solar renewable energy
1721	1721	22 credits required by this subparagraph (C), renewable
1722	1722	23 energy facilities that have a multi-year renewable
1723	1723	24 energy credit delivery contract with the utility
1724	1724	25 through at least delivery year 2030 shall be
1725	1725	26 considered new, however no renewable energy credits
1726	1726
1727	1727
1728	1728
1729	1729
1730	1730
1731	1731	HB5514 - 47 - LRB103 39335 CES 69496 b
1732	1732
1733	1733
1734	1734	HB5514- 48 -LRB103 39335 CES 69496 b HB5514 - 48 - LRB103 39335 CES 69496 b
1735	1735	HB5514 - 48 - LRB103 39335 CES 69496 b
1736	1736	1 from contracts entered into before June 1, 2021 shall
1737	1737	2 be used to calculate whether the Agency has procured
1738	1738	3 the correct proportion of new wind and new solar
1739	1739	4 contracts described in this subparagraph (C) for
1740	1740	5 delivery year 2021 and thereafter.
1741	1741	6 (c-7) Within 120 days after the effective date of this
1742	1742	7 amendatory Act of the 103rd General Assembly, the Agency shall
1743	1743	8 develop a one-time high voltage direct current renewable
1744	1744	9 energy credit procurement plan limited to the procurement of
1745	1745	10 high voltage direct current renewable energy credits.
1746	1746	11 (1) In addition to the procurement of renewable energy
1747	1747	12 credits pursuant to long-term renewable resources
1748	1748	13 procurement plans in accordance with subsection (c) of
1749	1749	14 this Section, Section 16-111.5 of the Public Utilities
1750	1750	15 Act, and the procurement of coal-to-solar renewable energy
1751	1751	16 credits in accordance with subsection (c-5) of this
1752	1752	17 Section, the Agency shall conduct procurement events in
1753	1753	18 accordance with this subsection (c-7) for the procurement
1754	1754	19 by electric utilities that served more than 300,000 retail
1755	1755	20 customers in this State as of January 1, 2019 of high
1756	1756	21 voltage direct current renewable energy credits and meet
1757	1757	22 the other criteria specified in this subsection (c-7). The
1758	1758	23 procurement of renewable energy credits by electric
1759	1759	24 utilities pursuant to this subsection (c-7) shall be
1760	1760	25 funded solely by revenues collected from the dispatchable
1761	1761	26 and reliable renewable energy charge provided for in this
1762	1762
1763	1763
1764	1764
1765	1765
1766	1766
1767	1767	HB5514 - 48 - LRB103 39335 CES 69496 b
1768	1768
1769	1769
1770	1770	HB5514- 49 -LRB103 39335 CES 69496 b HB5514 - 49 - LRB103 39335 CES 69496 b
1771	1771	HB5514 - 49 - LRB103 39335 CES 69496 b
1772	1772	1 subsection (c-7) and subsection (i-7) of Section 16-108 of
1773	1773	2 the Public Utilities Act, shall not be funded by revenues
1774	1774	3 collected through any of the other funding mechanisms
1775	1775	4 provided for in subsection (c) of this Section, and shall
1776	1776	5 not be subject to the limitation imposed by subsection (c)
1777	1777	6 on charges to retail customers for costs to procure
1778	1778	7 renewable energy resources pursuant to subsection (c), and
1779	1779	8 shall not be subject to any other requirements or
1780	1780	9 limitations of subsection (c).
1781	1781	10 (2) Within 5 days after the filing of the high voltage
1782	1782	11 direct current renewable energy credit procurement plan at
1783	1783	12 the Commission, any person objecting to the supplemental
1784	1784	13 procurement plan shall file an objection with the
1785	1785	14 Commission. Within 10 days after the filing, the
1786	1786	15 Commission shall determine whether a hearing is necessary.
1787	1787	16 The Commission shall enter its order confirming or
1788	1788	17 modifying the supplemental procurement plan within 90 days
1789	1789	18 after the filing of the supplemental procurement plan by
1790	1790	19 the Agency.
1791	1791	20 (3) The Commission shall approve the high voltage
1792	1792	21 direct current renewable energy credit procurement plan if
1793	1793	22 the Commission determines that it will ensure adequate,
1794	1794	23 reliable, affordable, efficient, and environmentally
1795	1795	24 sustainable electric service in the form of renewable
1796	1796	25 energy credits at the lowest total cost over time, taking
1797	1797	26 into account any benefits of price stability.
1798	1798
1799	1799
1800	1800
1801	1801
1802	1802
1803	1803	HB5514 - 49 - LRB103 39335 CES 69496 b
1804	1804
1805	1805
1806	1806	HB5514- 50 -LRB103 39335 CES 69496 b HB5514 - 50 - LRB103 39335 CES 69496 b
1807	1807	HB5514 - 50 - LRB103 39335 CES 69496 b
1808	1808	1 (4) The high voltage direct current renewable energy
1809	1809	2 credit procurement plan shall provide for procurement of
1810	1810	3 high voltage direct current renewable energy credits using
1811	1811	4 an indexed renewable energy credit structure as described
1812	1812	5 in item (v) of subparagraph (G) of paragraph (1) of
1813	1813	6 subsection (c) of this Section 1-75. The high voltage
1814	1814	7 direct current renewable energy credit procurement plan
1815	1815	8 shall procure a target volume of not less than 12,500,000
1816	1816	9 high voltage direct current renewable energy credits
1817	1817	10 delivered annually. Notwithstanding the preceding
1818	1818	11 provisions, the contracts for high voltage direct current
1819	1819	12 renewable energy credits shall contain the following
1820	1820	13 terms:
1821	1821	14 (i) delivery begins on the later of June 1, 2029
1822	1822	15 and energization of the associated high voltage direct
1823	1823	16 current transmission line, with additional reasonable
1824	1824	17 extensions available for delays in energization of the
1825	1825	18 generation facility;
1826	1826	19 (ii) the term shall be selected by the bidder to be
1827	1827	20 not less than 25 years and not more than 40 years;
1828	1828	21 (iii) the fuel type for the high voltage direct
1829	1829	22 current renewable energy credits shall be solar
1830	1830	23 photovoltaics or wind, or if insufficient high voltage
1831	1831	24 direct current renewable energy credits are available
1832	1832	25 from solar photovoltaics or wind, other fuel types
1833	1833	26 that qualify as a renewable resource under Section
1834	1834
1835	1835
1836	1836
1837	1837
1838	1838
1839	1839	HB5514 - 50 - LRB103 39335 CES 69496 b
1840	1840
1841	1841
1842	1842	HB5514- 51 -LRB103 39335 CES 69496 b HB5514 - 51 - LRB103 39335 CES 69496 b
1843	1843	HB5514 - 51 - LRB103 39335 CES 69496 b
1844	1844	1 1-10 of this Act;
1845	1845	2 (iv) monthly payment for renewable energy credits
1846	1846	3 actually delivered, not to exceed on a three-year
1847	1847	4 rolling average basis 120% of the annual delivery
1848	1848	5 quantity bid;
1849	1849	6 (v) a reasonable minimum annual delivery quantity
1850	1850	7 of high voltage direct current renewable energy
1851	1851	8 credits, however no penalties shall be assessed in the
1852	1852	9 event of force majeure, to the extent that the minimum
1853	1853	10 annual delivery quantity was missed due to less than
1854	1854	11 full dispatch of the high voltage direct current
1855	1855	12 converter station or curtailment of associated
1856	1856	13 generation during that same delivery year, or such
1857	1857	14 other reasonable exceptions as may be identified;
1858	1858	15 (vi) reasonable performance assurance and credit
1859	1859	16 requirements;
1860	1860	17 (vii) all high voltage direct current renewable
1861	1861	18 energy credits delivered must be generated from a
1862	1862	19 system that is energized or repowered on or after the
1863	1863	20 effective date of this Act; and
1864	1864	21 (viii) At any time after selection, the winning
1865	1865	22 bidder may change upon notice to the Agency the
1866	1866	23 generation source or anticipated generation source of
1867	1867	24 any high voltage direct current renewable energy
1868	1868	25 credits.
1869	1869	26 The high voltage direct current renewable energy credit
1870	1870
1871	1871
1872	1872
1873	1873
1874	1874
1875	1875	HB5514 - 51 - LRB103 39335 CES 69496 b
1876	1876
1877	1877
1878	1878	HB5514- 52 -LRB103 39335 CES 69496 b HB5514 - 52 - LRB103 39335 CES 69496 b
1879	1879	HB5514 - 52 - LRB103 39335 CES 69496 b
1880	1880	1 procurement plan shall allow the owner or operator, or the
1881	1881	2 owner's or operator's designee, to enter multiple bids,
1882	1882	3 provided that the same bid shall not include high-voltage
1883	1883	4 direct current renewable energy credits pledged in another
1884	1884	5 bid.
1885	1885	6 The high voltage direct current renewable energy credit
1886	1886	7 procurement plan shall not, subject to the preference for
1887	1887	8 solar photovoltaic and wind generation, prohibit or penalize
1888	1888	9 any renewable energy credits that meet the definition of high
1889	1889	10 voltage renewable energy credit in this Act.
1890	1890	11 The high voltage direct current renewable energy credit
1891	1891	12 procurement plan shall include a contingency plan if the
1892	1892	13 Agency procures less than 12,500,000 high voltage direct
1893	1893	14 current renewable energy credits annually or if one or more
1894	1894	15 winning bidders fails to deliver any high voltage direct
1895	1895	16 current renewable energy credits. The number of high voltage
1896	1896	17 direct current renewable energy credits to be procured as
1897	1897	18 specified in this paragraph (4) shall not be reduced based on
1898	1898	19 renewable energy credits procured in the self-direct renewable
1899	1899	20 energy credit compliance program established pursuant to
1900	1900	21 subparagraph (R) of paragraph (1) of subsection (c) of Section
1901	1901	22 1-75.
1902	1902	23 (5) The renewable energy credits procured pursuant to
1903	1903	24 the high voltage direct current renewable energy credit
1904	1904	25 procurement plan shall be procured in accordance with the
1905	1905	26 Agency and Commission's process competitive procurement in
1906	1906
1907	1907
1908	1908
1909	1909
1910	1910
1911	1911	HB5514 - 52 - LRB103 39335 CES 69496 b
1912	1912
1913	1913
1914	1914	HB5514- 53 -LRB103 39335 CES 69496 b HB5514 - 53 - LRB103 39335 CES 69496 b
1915	1915	HB5514 - 53 - LRB103 39335 CES 69496 b
1916	1916	1 subsections (e) through (p) of Section 16-111.5 of the
1917	1917	2 Public Utilities Act, as applicable. Notwithstanding
1918	1918	3 anything in Section 16-111.5 of the Public Utilities Act:
1919	1919	4 (A) To ensure the delivery of high voltage direct
1920	1920	5 current renewable energy credits, the high voltage
1921	1921	6 direct current renewable energy credit procurement
1922	1922	7 plan shall provide that only the owner or operator of a
1923	1923	8 high voltage direct current transmission line or its
1924	1924	9 designee may bid in the procurements described in this
1925	1925	10 subsection (c-7). For the purposes of this paragraph,
1926	1926	11 the owner or operator, or the owner's or operator's
1927	1927	12 designee, must demonstrate that it has site control of
1928	1928	13 at least 90 miles route located within Illinois, and
1929	1929	14 plans reflecting 525 kV or greater delivery voltage
1930	1930	15 and construction of at least 100 miles of transmission
1931	1931	16 line underground in Illinois. For the purpose of this
1932	1932	17 subparagraph, "site control" may include easements,
1933	1933	18 leases, options for leases, or any similar indicia of
1934	1934	19 site control identified by the Agency.
1935	1935	20 (B) For the purpose of the competitive
1936	1936	21 procurement, a bid shall be a price and quantity of
1937	1937	22 high voltage direct current renewable energy credits.
1938	1938	23 Each bid shall be for a quantity of not less than
1939	1939	24 5,000,000 high voltage direct current renewable energy
1940	1940	25 credits annually.
1941	1941	26 (C) The Agency shall only procure cost-effective
1942	1942
1943	1943
1944	1944
1945	1945
1946	1946
1947	1947	HB5514 - 53 - LRB103 39335 CES 69496 b
1948	1948
1949	1949
1950	1950	HB5514- 54 -LRB103 39335 CES 69496 b HB5514 - 54 - LRB103 39335 CES 69496 b
1951	1951	HB5514 - 54 - LRB103 39335 CES 69496 b
1952	1952	1 high voltage direct current renewable energy credits.
1953	1953	2 For the purposes of this subsection (c-7),
1954	1954	3 "cost-effective" shall mean the high voltage direct
1955	1955	4 current renewable energy credits shall not exceed
1956	1956	5 benchmarks based on market prices for high voltage
1957	1957	6 direct current renewable energy credits.
1958	1958	7 (D) Each competitive bid shall specifically
1959	1959	8 identify the price charged by the high voltage direct
1960	1960	9 current transmission line. The benchmark established
1961	1961	10 in accordance with subsection (e) of Section 16-111.5
1962	1962	11 of the Public Utilities Act shall be applied to the bid
1963	1963	12 price minus the line item for the price charged by the
1964	1964	13 high voltage direct current transmission line.
1965	1965	14 Notwithstanding anything to the contrary in this Act or
1966	1966	15 the Public Utilities Act, in developing the benchmark the
1967	1967	16 Procurement Administrator shall use values for the capital and
1968	1968	17 costs for a high voltage direct current transmission line. The
1969	1969	18 Capital Development Board shall calculate a range of capital
1970	1970	19 costs that it believes would be reasonable for an HVDC
1971	1971	20 transmission line of similar specifications to an applicant
1972	1972	21 high voltage direct current transmission line. The Capital
1973	1973	22 Development Board may consult as much as it deems necessary
1974	1974	23 with applicant or potential applicant high voltage direct
1975	1975	24 current transmission lines and conduct whatever research and
1976	1976	25 investigation it deems necessary. The Capital Development
1977	1977	26 Board shall retain an engineering expert in making such
1978	1978
1979	1979
1980	1980
1981	1981
1982	1982
1983	1983	HB5514 - 54 - LRB103 39335 CES 69496 b
1984	1984
1985	1985
1986	1986	HB5514- 55 -LRB103 39335 CES 69496 b HB5514 - 55 - LRB103 39335 CES 69496 b
1987	1987	HB5514 - 55 - LRB103 39335 CES 69496 b
1988	1988	1 determination with at least ten years of experience in
1989	1989	2 transmission and merchant transmission development and
1990	1990	3 experience with high voltage direct current transmission. The
1991	1991	4 expert shall: (i) not own or control any direct or indirect
1992	1992	5 interest in the high voltage direct current transmission line,
1993	1993	6 and (iii) have no contractual relationship with the high
1994	1994	7 voltage direct current transmission line.
1995	1995	8 (E) The contract price shall the original bid price of
1996	1996	9 each winning bidder, inclusive of the costs charged by the
1997	1997	10 high voltage direct current transmission line.
1998	1998	11 (F) For the purposes of this paragraph (4), all
1999	1999	12 information about high voltage direct current transmission
2000	2000	13 line pricing shall be maintained as highly confidential
2001	2001	14 and not disclosed by the Agency, Commission, or any third
2002	2002	15 party otherwise privy to such information.
2003	2003	16 (6) The Agency and its procurement administrator shall
2004	2004	17 administer the procurement authorized in the high voltage
2005	2005	18 direct current renewable energy credit procurement plan not
2006	2006	19 later than December 31, 2024.
2007	2007	20 (7) The Agency shall assess fees to each applicant to
2008	2008	21 recover the Agency's costs incurred in receiving and
2009	2009	22 evaluating applications, conducting the procurement event,
2010	2010	23 developing contracts for sale, delivery and purchase of
2011	2011	24 renewable energy credits, and monitoring the administration of
2012	2012	25 such contracts, as provided for in this subsection (c-7),
2013	2013	26 including fees paid to a procurement administrator retained by
2014	2014
2015	2015
2016	2016
2017	2017
2018	2018
2019	2019	HB5514 - 55 - LRB103 39335 CES 69496 b
2020	2020
2021	2021
2022	2022	HB5514- 56 -LRB103 39335 CES 69496 b HB5514 - 56 - LRB103 39335 CES 69496 b
2023	2023	HB5514 - 56 - LRB103 39335 CES 69496 b
2024	2024	1 the Agency for one or more of these purposes.
2025	2025	2 (8) The obligation to purchase high voltage direct current
2026	2026	3 renewable energy credits selected by the Agency shall be
2027	2027	4 allocated to the electric utilities based on their respective
2028	2028	5 percentages of kilowatthours delivered to delivery services
2029	2029	6 customers to the aggregate kilowatthour deliveries by the
2030	2030	7 electric utilities to delivery services customers for the year
2031	2031	8 ended December 31, 2021. In order to achieve these allocation
2032	2032	9 percentages between or among the electric utilities, the
2033	2033	10 Agency shall require each applicant that is selected in the
2034	2034	11 procurement event to enter into a contract with each electric
2035	2035	12 utility for the sale and purchase of high voltage direct
2036	2036	13 current renewable energy credits meeting the standards of this
2037	2037	14 subsection (c-7), with the sale and purchase obligations under
2038	2038	15 the contracts to aggregate to the total number of high voltage
2039	2039	16 direct current renewable energy credits per year to be
2040	2040	17 supplied by the applicant.
2041	2041	18 (D) Renewable energy credits shall be cost effective.
2042	2042	19 For purposes of this subsection (c), "cost effective"
2043	2043	20 means that the costs of procuring renewable energy
2044	2044	21 resources do not cause the limit stated in subparagraph
2045	2045	22 (E) of this paragraph (1) to be exceeded and, for
2046	2046	23 renewable energy credits procured through a competitive
2047	2047	24 procurement event, do not exceed benchmarks based on
2048	2048	25 market prices for like products in the region. For
2049	2049	26 purposes of this subsection (c), "like products" means
2050	2050
2051	2051
2052	2052
2053	2053
2054	2054
2055	2055	HB5514 - 56 - LRB103 39335 CES 69496 b
2056	2056
2057	2057
2058	2058	HB5514- 57 -LRB103 39335 CES 69496 b HB5514 - 57 - LRB103 39335 CES 69496 b
2059	2059	HB5514 - 57 - LRB103 39335 CES 69496 b
2060	2060	1 contracts for renewable energy credits from the same or
2061	2061	2 substantially similar technology, same or substantially
2062	2062	3 similar vintage (new or existing), the same or
2063	2063	4 substantially similar quantity, and the same or
2064	2064	5 substantially similar contract length and structure.
2065	2065	6 Benchmarks shall reflect development, financing, or
2066	2066	7 related costs resulting from requirements imposed through
2067	2067	8 other provisions of State law, including, but not limited
2068	2068	9 to, requirements in subparagraphs (P) and (Q) of this
2069	2069	10 paragraph (1) and the Renewable Energy Facilities
2070	2070	11 Agricultural Impact Mitigation Act. Confidential
2071	2071	12 benchmarks shall be developed by the procurement
2072	2072	13 administrator, in consultation with the Commission staff,
2073	2073	14 Agency staff, and the procurement monitor and shall be
2074	2074	15 subject to Commission review and approval. If price
2075	2075	16 benchmarks for like products in the region are not
2076	2076	17 available, the procurement administrator shall establish
2077	2077	18 price benchmarks based on publicly available data on
2078	2078	19 regional technology costs and expected current and future
2079	2079	20 regional energy prices. The benchmarks in this Section
2080	2080	21 shall not be used to curtail or otherwise reduce
2081	2081	22 contractual obligations entered into by or through the
2082	2082	23 Agency prior to June 1, 2017 (the effective date of Public
2083	2083	24 Act 99-906).
2084	2084	25 (E) For purposes of this subsection (c), the required
2085	2085	26 procurement of cost-effective renewable energy resources
2086	2086
2087	2087
2088	2088
2089	2089
2090	2090
2091	2091	HB5514 - 57 - LRB103 39335 CES 69496 b
2092	2092
2093	2093
2094	2094	HB5514- 58 -LRB103 39335 CES 69496 b HB5514 - 58 - LRB103 39335 CES 69496 b
2095	2095	HB5514 - 58 - LRB103 39335 CES 69496 b
2096	2096	1 for a particular year commencing prior to June 1, 2017
2097	2097	2 shall be measured as a percentage of the actual amount of
2098	2098	3 electricity (megawatt-hours) supplied by the electric
2099	2099	4 utility to eligible retail customers in the delivery year
2100	2100	5 ending immediately prior to the procurement, and, for
2101	2101	6 delivery years commencing on and after June 1, 2017, the
2102	2102	7 required procurement of cost-effective renewable energy
2103	2103	8 resources for a particular year shall be measured as a
2104	2104	9 percentage of the actual amount of electricity
2105	2105	10 (megawatt-hours) delivered by the electric utility in the
2106	2106	11 delivery year ending immediately prior to the procurement,
2107	2107	12 to all retail customers in its service territory. For
2108	2108	13 purposes of this subsection (c), the amount paid per
2109	2109	14 kilowatthour means the total amount paid for electric
2110	2110	15 service expressed on a per kilowatthour basis. For
2111	2111	16 purposes of this subsection (c), the total amount paid for
2112	2112	17 electric service includes without limitation amounts paid
2113	2113	18 for supply, transmission, capacity, distribution,
2114	2114	19 surcharges, and add-on taxes.
2115	2115	20 Notwithstanding the requirements of this subsection
2116	2116	21 (c), the total of renewable energy resources procured
2117	2117	22 under the procurement plan for any single year shall be
2118	2118	23 subject to the limitations of this subparagraph (E). Such
2119	2119	24 procurement shall be reduced for all retail customers
2120	2120	25 based on the amount necessary to limit the annual
2121	2121	26 estimated average net increase due to the costs of these
2122	2122
2123	2123
2124	2124
2125	2125
2126	2126
2127	2127	HB5514 - 58 - LRB103 39335 CES 69496 b
2128	2128
2129	2129
2130	2130	HB5514- 59 -LRB103 39335 CES 69496 b HB5514 - 59 - LRB103 39335 CES 69496 b
2131	2131	HB5514 - 59 - LRB103 39335 CES 69496 b
2132	2132	1 resources included in the amounts paid by eligible retail
2133	2133	2 customers in connection with electric service to no more
2134	2134	3 than 4.25% of the amount paid per kilowatthour by those
2135	2135	4 customers during the year ending May 31, 2009. To arrive
2136	2136	5 at a maximum dollar amount of renewable energy resources
2137	2137	6 to be procured for the particular delivery year, the
2138	2138	7 resulting per kilowatthour amount shall be applied to the
2139	2139	8 actual amount of kilowatthours of electricity delivered,
2140	2140	9 or applicable portion of such amount as specified in
2141	2141	10 paragraph (1) of this subsection (c), as applicable, by
2142	2142	11 the electric utility in the delivery year immediately
2143	2143	12 prior to the procurement to all retail customers in its
2144	2144	13 service territory. The calculations required by this
2145	2145	14 subparagraph (E) shall be made only once for each delivery
2146	2146	15 year at the time that the renewable energy resources are
2147	2147	16 procured. Once the determination as to the amount of
2148	2148	17 renewable energy resources to procure is made based on the
2149	2149	18 calculations set forth in this subparagraph (E) and the
2150	2150	19 contracts procuring those amounts are executed, no
2151	2151	20 subsequent rate impact determinations shall be made and no
2152	2152	21 adjustments to those contract amounts shall be allowed.
2153	2153	22 All costs incurred under such contracts shall be fully
2154	2154	23 recoverable by the electric utility as provided in this
2155	2155	24 Section.
2156	2156	25 (F) If the limitation on the amount of renewable
2157	2157	26 energy resources procured in subparagraph (E) of this
2158	2158
2159	2159
2160	2160
2161	2161
2162	2162
2163	2163	HB5514 - 59 - LRB103 39335 CES 69496 b
2164	2164
2165	2165
2166	2166	HB5514- 60 -LRB103 39335 CES 69496 b HB5514 - 60 - LRB103 39335 CES 69496 b
2167	2167	HB5514 - 60 - LRB103 39335 CES 69496 b
2168	2168	1 paragraph (1) prevents the Agency from meeting all of the
2169	2169	2 goals in this subsection (c), the Agency's long-term plan
2170	2170	3 shall prioritize compliance with the requirements of this
2171	2171	4 subsection (c) regarding renewable energy credits in the
2172	2172	5 following order:
2173	2173	6 (i) renewable energy credits under existing
2174	2174	7 contractual obligations as of June 1, 2021;
2175	2175	8 (i-5) funding for the Illinois Solar for All
2176	2176	9 Program, as described in subparagraph (O) of this
2177	2177	10 paragraph (1);
2178	2178	11 (ii) renewable energy credits necessary to comply
2179	2179	12 with the new wind and new photovoltaic procurement
2180	2180	13 requirements described in items (i) through (iii) of
2181	2181	14 subparagraph (C) of this paragraph (1); and
2182	2182	15 (iii) renewable energy credits necessary to meet
2183	2183	16 the remaining requirements of this subsection (c).
2184	2184	17 (G) The following provisions shall apply to the
2185	2185	18 Agency's procurement of renewable energy credits under
2186	2186	19 this subsection (c):
2187	2187	20 (i) Notwithstanding whether a long-term renewable
2188	2188	21 resources procurement plan has been approved, the
2189	2189	22 Agency shall conduct an initial forward procurement
2190	2190	23 for renewable energy credits from new utility-scale
2191	2191	24 wind projects within 160 days after June 1, 2017 (the
2192	2192	25 effective date of Public Act 99-906). For the purposes
2193	2193	26 of this initial forward procurement, the Agency shall
2194	2194
2195	2195
2196	2196
2197	2197
2198	2198
2199	2199	HB5514 - 60 - LRB103 39335 CES 69496 b
2200	2200
2201	2201
2202	2202	HB5514- 61 -LRB103 39335 CES 69496 b HB5514 - 61 - LRB103 39335 CES 69496 b
2203	2203	HB5514 - 61 - LRB103 39335 CES 69496 b
2204	2204	1 solicit 15-year contracts for delivery of 1,000,000
2205	2205	2 renewable energy credits delivered annually from new
2206	2206	3 utility-scale wind projects to begin delivery on June
2207	2207	4 1, 2019, if available, but not later than June 1, 2021,
2208	2208	5 unless the project has delays in the establishment of
2209	2209	6 an operating interconnection with the applicable
2210	2210	7 transmission or distribution system as a result of the
2211	2211	8 actions or inactions of the transmission or
2212	2212	9 distribution provider, or other causes for force
2213	2213	10 majeure as outlined in the procurement contract, in
2214	2214	11 which case, not later than June 1, 2022. Payments to
2215	2215	12 suppliers of renewable energy credits shall commence
2216	2216	13 upon delivery. Renewable energy credits procured under
2217	2217	14 this initial procurement shall be included in the
2218	2218	15 Agency's long-term plan and shall apply to all
2219	2219	16 renewable energy goals in this subsection (c).
2220	2220	17 (ii) Notwithstanding whether a long-term renewable
2221	2221	18 resources procurement plan has been approved, the
2222	2222	19 Agency shall conduct an initial forward procurement
2223	2223	20 for renewable energy credits from new utility-scale
2224	2224	21 solar projects and brownfield site photovoltaic
2225	2225	22 projects within one year after June 1, 2017 (the
2226	2226	23 effective date of Public Act 99-906). For the purposes
2227	2227	24 of this initial forward procurement, the Agency shall
2228	2228	25 solicit 15-year contracts for delivery of 1,000,000
2229	2229	26 renewable energy credits delivered annually from new
2230	2230
2231	2231
2232	2232
2233	2233
2234	2234
2235	2235	HB5514 - 61 - LRB103 39335 CES 69496 b
2236	2236
2237	2237
2238	2238	HB5514- 62 -LRB103 39335 CES 69496 b HB5514 - 62 - LRB103 39335 CES 69496 b
2239	2239	HB5514 - 62 - LRB103 39335 CES 69496 b
2240	2240	1 utility-scale solar projects and brownfield site
2241	2241	2 photovoltaic projects to begin delivery on June 1,
2242	2242	3 2019, if available, but not later than June 1, 2021,
2243	2243	4 unless the project has delays in the establishment of
2244	2244	5 an operating interconnection with the applicable
2245	2245	6 transmission or distribution system as a result of the
2246	2246	7 actions or inactions of the transmission or
2247	2247	8 distribution provider, or other causes for force
2248	2248	9 majeure as outlined in the procurement contract, in
2249	2249	10 which case, not later than June 1, 2022. The Agency may
2250	2250	11 structure this initial procurement in one or more
2251	2251	12 discrete procurement events. Payments to suppliers of
2252	2252	13 renewable energy credits shall commence upon delivery.
2253	2253	14 Renewable energy credits procured under this initial
2254	2254	15 procurement shall be included in the Agency's
2255	2255	16 long-term plan and shall apply to all renewable energy
2256	2256	17 goals in this subsection (c).
2257	2257	18 (iii) Notwithstanding whether the Commission has
2258	2258	19 approved the periodic long-term renewable resources
2259	2259	20 procurement plan revision described in Section
2260	2260	21 16-111.5 of the Public Utilities Act, the Agency shall
2261	2261	22 conduct at least one subsequent forward procurement
2262	2262	23 for renewable energy credits from new utility-scale
2263	2263	24 wind projects, new utility-scale solar projects, and
2264	2264	25 new brownfield site photovoltaic projects within 240
2265	2265	26 days after the effective date of this amendatory Act
2266	2266
2267	2267
2268	2268
2269	2269
2270	2270
2271	2271	HB5514 - 62 - LRB103 39335 CES 69496 b
2272	2272
2273	2273
2274	2274	HB5514- 63 -LRB103 39335 CES 69496 b HB5514 - 63 - LRB103 39335 CES 69496 b
2275	2275	HB5514 - 63 - LRB103 39335 CES 69496 b
2276	2276	1 of the 102nd General Assembly in quantities necessary
2277	2277	2 to meet the requirements of subparagraph (C) of this
2278	2278	3 paragraph (1) through the delivery year beginning June
2279	2279	4 1, 2021.
2280	2280	5 (iv) Notwithstanding whether the Commission has
2281	2281	6 approved the periodic long-term renewable resources
2282	2282	7 procurement plan revision described in Section
2283	2283	8 16-111.5 of the Public Utilities Act, the Agency shall
2284	2284	9 open capacity for each category in the Adjustable
2285	2285	10 Block program within 90 days after the effective date
2286	2286	11 of this amendatory Act of the 102nd General Assembly
2287	2287	12 manner:
2288	2288	13 (1) The Agency shall open the first block of
2289	2289	14 annual capacity for the category described in item
2290	2290	15 (i) of subparagraph (K) of this paragraph (1). The
2291	2291	16 first block of annual capacity for item (i) shall
2292	2292	17 be for at least 75 megawatts of total nameplate
2293	2293	18 capacity. The price of the renewable energy credit
2294	2294	19 for this block of capacity shall be 4% less than
2295	2295	20 the price of the last open block in this category.
2296	2296	21 Projects on a waitlist shall be awarded contracts
2297	2297	22 first in the order in which they appear on the
2298	2298	23 waitlist. Notwithstanding anything to the
2299	2299	24 contrary, for those renewable energy credits that
2300	2300	25 qualify and are procured under this subitem (1) of
2301	2301	26 this item (iv), the renewable energy credit
2302	2302
2303	2303
2304	2304
2305	2305
2306	2306
2307	2307	HB5514 - 63 - LRB103 39335 CES 69496 b
2308	2308
2309	2309
2310	2310	HB5514- 64 -LRB103 39335 CES 69496 b HB5514 - 64 - LRB103 39335 CES 69496 b
2311	2311	HB5514 - 64 - LRB103 39335 CES 69496 b
2312	2312	1 delivery contract value shall be paid in full,
2313	2313	2 based on the estimated generation during the first
2314	2314	3 15 years of operation, by the contracting
2315	2315	4 utilities at the time that the facility producing
2316	2316	5 the renewable energy credits is interconnected at
2317	2317	6 the distribution system level of the utility and
2318	2318	7 verified as energized and in compliance by the
2319	2319	8 Program Administrator. The electric utility shall
2320	2320	9 receive and retire all renewable energy credits
2321	2321	10 generated by the project for the first 15 years of
2322	2322	11 operation. Renewable energy credits generated by
2323	2323	12 the project thereafter shall not be transferred
2324	2324	13 under the renewable energy credit delivery
2325	2325	14 contract with the counterparty electric utility.
2326	2326	15 (2) The Agency shall open the first block of
2327	2327	16 annual capacity for the category described in item
2328	2328	17 (ii) of subparagraph (K) of this paragraph (1).
2329	2329	18 The first block of annual capacity for item (ii)
2330	2330	19 shall be for at least 75 megawatts of total
2331	2331	20 nameplate capacity.
2332	2332	21 (A) The price of the renewable energy
2333	2333	22 credit for any project on a waitlist for this
2334	2334	23 category before the opening of this block
2335	2335	24 shall be 4% less than the price of the last
2336	2336	25 open block in this category. Projects on the
2337	2337	26 waitlist shall be awarded contracts first in
2338	2338
2339	2339
2340	2340
2341	2341
2342	2342
2343	2343	HB5514 - 64 - LRB103 39335 CES 69496 b
2344	2344
2345	2345
2346	2346	HB5514- 65 -LRB103 39335 CES 69496 b HB5514 - 65 - LRB103 39335 CES 69496 b
2347	2347	HB5514 - 65 - LRB103 39335 CES 69496 b
2348	2348	1 the order in which they appear on the
2349	2349	2 waitlist. Any projects that are less than or
2350	2350	3 equal to 25 kilowatts in size on the waitlist
2351	2351	4 for this capacity shall be moved to the
2352	2352	5 waitlist for paragraph (1) of this item (iv).
2353	2353	6 Notwithstanding anything to the contrary,
2354	2354	7 projects that were on the waitlist prior to
2355	2355	8 opening of this block shall not be required to
2356	2356	9 be in compliance with the requirements of
2357	2357	10 subparagraph (Q) of this paragraph (1) of this
2358	2358	11 subsection (c). Notwithstanding anything to
2359	2359	12 the contrary, for those renewable energy
2360	2360	13 credits procured from projects that were on
2361	2361	14 the waitlist for this category before the
2362	2362	15 opening of this block 20% of the renewable
2363	2363	16 energy credit delivery contract value, based
2364	2364	17 on the estimated generation during the first
2365	2365	18 15 years of operation, shall be paid by the
2366	2366	19 contracting utilities at the time that the
2367	2367	20 facility producing the renewable energy
2368	2368	21 credits is interconnected at the distribution
2369	2369	22 system level of the utility and verified as
2370	2370	23 energized by the Program Administrator. The
2371	2371	24 remaining portion shall be paid ratably over
2372	2372	25 the subsequent 4-year period. The electric
2373	2373	26 utility shall receive and retire all renewable
2374	2374
2375	2375
2376	2376
2377	2377
2378	2378
2379	2379	HB5514 - 65 - LRB103 39335 CES 69496 b
2380	2380
2381	2381
2382	2382	HB5514- 66 -LRB103 39335 CES 69496 b HB5514 - 66 - LRB103 39335 CES 69496 b
2383	2383	HB5514 - 66 - LRB103 39335 CES 69496 b
2384	2384	1 energy credits generated by the project during
2385	2385	2 the first 15 years of operation. Renewable
2386	2386	3 energy credits generated by the project
2387	2387	4 thereafter shall not be transferred under the
2388	2388	5 renewable energy credit delivery contract with
2389	2389	6 the counterparty electric utility.
2390	2390	7 (B) The price of renewable energy credits
2391	2391	8 for any project not on the waitlist for this
2392	2392	9 category before the opening of the block shall
2393	2393	10 be determined and published by the Agency.
2394	2394	11 Projects not on a waitlist as of the opening
2395	2395	12 of this block shall be subject to the
2396	2396	13 requirements of subparagraph (Q) of this
2397	2397	14 paragraph (1), as applicable. Projects not on
2398	2398	15 a waitlist as of the opening of this block
2399	2399	16 shall be subject to the contract provisions
2400	2400	17 outlined in item (iii) of subparagraph (L) of
2401	2401	18 this paragraph (1). The Agency shall strive to
2402	2402	19 publish updated prices and an updated
2403	2403	20 renewable energy credit delivery contract as
2404	2404	21 quickly as possible.
2405	2405	22 (3) For opening the first 2 blocks of annual
2406	2406	23 capacity for projects participating in item (iii)
2407	2407	24 of subparagraph (K) of paragraph (1) of subsection
2408	2408	25 (c), projects shall be selected exclusively from
2409	2409	26 those projects on the ordinal waitlists of
2410	2410
2411	2411
2412	2412
2413	2413
2414	2414
2415	2415	HB5514 - 66 - LRB103 39335 CES 69496 b
2416	2416
2417	2417
2418	2418	HB5514- 67 -LRB103 39335 CES 69496 b HB5514 - 67 - LRB103 39335 CES 69496 b
2419	2419	HB5514 - 67 - LRB103 39335 CES 69496 b
2420	2420	1 community renewable generation projects
2421	2421	2 established by the Agency based on the status of
2422	2422	3 those ordinal waitlists as of December 31, 2020,
2423	2423	4 and only those projects previously determined to
2424	2424	5 be eligible for the Agency's April 2019 community
2425	2425	6 solar project selection process.
2426	2426	7 The first 2 blocks of annual capacity for item
2427	2427	8 (iii) shall be for 250 megawatts of total
2428	2428	9 nameplate capacity, with both blocks opening
2429	2429	10 simultaneously under the schedule outlined in the
2430	2430	11 paragraphs below. Projects shall be selected as
2431	2431	12 follows:
2432	2432	13 (A) The geographic balance of selected
2433	2433	14 projects shall follow the Group classification
2434	2434	15 found in the Agency's Revised Long-Term
2435	2435	16 Renewable Resources Procurement Plan, with 70%
2436	2436	17 of capacity allocated to projects on the Group
2437	2437	18 B waitlist and 30% of capacity allocated to
2438	2438	19 projects on the Group A waitlist.
2439	2439	20 (B) Contract awards for waitlisted
2440	2440	21 projects shall be allocated proportionate to
2441	2441	22 the total nameplate capacity amount across
2442	2442	23 both ordinal waitlists associated with that
2443	2443	24 applicant firm or its affiliates, subject to
2444	2444	25 the following conditions.
2445	2445	26 (i) Each applicant firm having a
2446	2446
2447	2447
2448	2448
2449	2449
2450	2450
2451	2451	HB5514 - 67 - LRB103 39335 CES 69496 b
2452	2452
2453	2453
2454	2454	HB5514- 68 -LRB103 39335 CES 69496 b HB5514 - 68 - LRB103 39335 CES 69496 b
2455	2455	HB5514 - 68 - LRB103 39335 CES 69496 b
2456	2456	1 waitlisted project eligible for selection
2457	2457	2 shall receive no less than 500 kilowatts
2458	2458	3 in awarded capacity across all groups, and
2459	2459	4 no approved vendor may receive more than
2460	2460	5 20% of each Group's waitlist allocation.
2461	2461	6 (ii) Each applicant firm, upon
2462	2462	7 receiving an award of program capacity
2463	2463	8 proportionate to its waitlisted capacity,
2464	2464	9 may then determine which waitlisted
2465	2465	10 projects it chooses to be selected for a
2466	2466	11 contract award up to that capacity amount.
2467	2467	12 (iii) Assuming all other program
2468	2468	13 requirements are met, applicant firms may
2469	2469	14 adjust the nameplate capacity of applicant
2470	2470	15 projects without losing waitlist
2471	2471	16 eligibility, so long as no project is
2472	2472	17 greater than 2,000 kilowatts in size.
2473	2473	18 (iv) Assuming all other program
2474	2474	19 requirements are met, applicant firms may
2475	2475	20 adjust the expected production associated
2476	2476	21 with applicant projects, subject to
2477	2477	22 verification by the Program Administrator.
2478	2478	23 (C) After a review of affiliate
2479	2479	24 information and the current ordinal waitlists,
2480	2480	25 the Agency shall announce the nameplate
2481	2481	26 capacity award amounts associated with
2482	2482
2483	2483
2484	2484
2485	2485
2486	2486
2487	2487	HB5514 - 68 - LRB103 39335 CES 69496 b
2488	2488
2489	2489
2490	2490	HB5514- 69 -LRB103 39335 CES 69496 b HB5514 - 69 - LRB103 39335 CES 69496 b
2491	2491	HB5514 - 69 - LRB103 39335 CES 69496 b
2492	2492	1 applicant firms no later than 90 days after
2493	2493	2 the effective date of this amendatory Act of
2494	2494	3 the 102nd General Assembly.
2495	2495	4 (D) Applicant firms shall submit their
2496	2496	5 portfolio of projects used to satisfy those
2497	2497	6 contract awards no less than 90 days after the
2498	2498	7 Agency's announcement. The total nameplate
2499	2499	8 capacity of all projects used to satisfy that
2500	2500	9 portfolio shall be no greater than the
2501	2501	10 Agency's nameplate capacity award amount
2502	2502	11 associated with that applicant firm. An
2503	2503	12 applicant firm may decline, in whole or in
2504	2504	13 part, its nameplate capacity award without
2505	2505	14 penalty, with such unmet capacity rolled over
2506	2506	15 to the next block opening for project
2507	2507	16 selection under item (iii) of subparagraph (K)
2508	2508	17 of this subsection (c). Any projects not
2509	2509	18 included in an applicant firm's portfolio may
2510	2510	19 reapply without prejudice upon the next block
2511	2511	20 reopening for project selection under item
2512	2512	21 (iii) of subparagraph (K) of this subsection
2513	2513	22 (c).
2514	2514	23 (E) The renewable energy credit delivery
2515	2515	24 contract shall be subject to the contract and
2516	2516	25 payment terms outlined in item (iv) of
2517	2517	26 subparagraph (L) of this subsection (c).
2518	2518
2519	2519
2520	2520
2521	2521
2522	2522
2523	2523	HB5514 - 69 - LRB103 39335 CES 69496 b
2524	2524
2525	2525
2526	2526	HB5514- 70 -LRB103 39335 CES 69496 b HB5514 - 70 - LRB103 39335 CES 69496 b
2527	2527	HB5514 - 70 - LRB103 39335 CES 69496 b
2528	2528	1 Contract instruments used for this
2529	2529	2 subparagraph shall contain the following
2530	2530	3 terms:
2531	2531	4 (i) Renewable energy credit prices
2532	2532	5 shall be fixed, without further adjustment
2533	2533	6 under any other provision of this Act or
2534	2534	7 for any other reason, at 10% lower than
2535	2535	8 prices applicable to the last open block
2536	2536	9 for this category, inclusive of any adders
2537	2537	10 available for achieving a minimum of 50%
2538	2538	11 of subscribers to the project's nameplate
2539	2539	12 capacity being residential or small
2540	2540	13 commercial customers with subscriptions of
2541	2541	14 below 25 kilowatts in size;
2542	2542	15 (ii) A requirement that a minimum of
2543	2543	16 50% of subscribers to the project's
2544	2544	17 nameplate capacity be residential or small
2545	2545	18 commercial customers with subscriptions of
2546	2546	19 below 25 kilowatts in size;
2547	2547	20 (iii) Permission for the ability of a
2548	2548	21 contract holder to substitute projects
2549	2549	22 with other waitlisted projects without
2550	2550	23 penalty should a project receive a
2551	2551	24 non-binding estimate of costs to construct
2552	2552	25 the interconnection facilities and any
2553	2553	26 required distribution upgrades associated
2554	2554
2555	2555
2556	2556
2557	2557
2558	2558
2559	2559	HB5514 - 70 - LRB103 39335 CES 69496 b
2560	2560
2561	2561
2562	2562	HB5514- 71 -LRB103 39335 CES 69496 b HB5514 - 71 - LRB103 39335 CES 69496 b
2563	2563	HB5514 - 71 - LRB103 39335 CES 69496 b
2564	2564	1 with that project of greater than 30 cents
2565	2565	2 per watt AC of that project's nameplate
2566	2566	3 capacity. In developing the applicable
2567	2567	4 contract instrument, the Agency may
2568	2568	5 consider whether other circumstances
2569	2569	6 outside of the control of the applicant
2570	2570	7 firm should also warrant project
2571	2571	8 substitution rights.
2572	2572	9 The Agency shall publish a finalized
2573	2573	10 updated renewable energy credit delivery
2574	2574	11 contract developed consistent with these terms
2575	2575	12 and conditions no less than 30 days before
2576	2576	13 applicant firms must submit their portfolio of
2577	2577	14 projects pursuant to item (D).
2578	2578	15 (F) To be eligible for an award, the
2579	2579	16 applicant firm shall certify that not less
2580	2580	17 than prevailing wage, as determined pursuant
2581	2581	18 to the Illinois Prevailing Wage Act, was or
2582	2582	19 will be paid to employees who are engaged in
2583	2583	20 construction activities associated with a
2584	2584	21 selected project.
2585	2585	22 (4) The Agency shall open the first block of
2586	2586	23 annual capacity for the category described in item
2587	2587	24 (iv) of subparagraph (K) of this paragraph (1).
2588	2588	25 The first block of annual capacity for item (iv)
2589	2589	26 shall be for at least 50 megawatts of total
2590	2590
2591	2591
2592	2592
2593	2593
2594	2594
2595	2595	HB5514 - 71 - LRB103 39335 CES 69496 b
2596	2596
2597	2597
2598	2598	HB5514- 72 -LRB103 39335 CES 69496 b HB5514 - 72 - LRB103 39335 CES 69496 b
2599	2599	HB5514 - 72 - LRB103 39335 CES 69496 b
2600	2600	1 nameplate capacity. Renewable energy credit prices
2601	2601	2 shall be fixed, without further adjustment under
2602	2602	3 any other provision of this Act or for any other
2603	2603	4 reason, at the price in the last open block in the
2604	2604	5 category described in item (ii) of subparagraph
2605	2605	6 (K) of this paragraph (1). Pricing for future
2606	2606	7 blocks of annual capacity for this category may be
2607	2607	8 adjusted in the Agency's second revision to its
2608	2608	9 Long-Term Renewable Resources Procurement Plan.
2609	2609	10 Projects in this category shall be subject to the
2610	2610	11 contract terms outlined in item (iv) of
2611	2611	12 subparagraph (L) of this paragraph (1).
2612	2612	13 (5) The Agency shall open the equivalent of 2
2613	2613	14 years of annual capacity for the category
2614	2614	15 described in item (v) of subparagraph (K) of this
2615	2615	16 paragraph (1). The first block of annual capacity
2616	2616	17 for item (v) shall be for at least 10 megawatts of
2617	2617	18 total nameplate capacity. Notwithstanding the
2618	2618	19 provisions of item (v) of subparagraph (K) of this
2619	2619	20 paragraph (1), for the purpose of this initial
2620	2620	21 block, the agency shall accept new project
2621	2621	22 applications intended to increase the diversity of
2622	2622	23 areas hosting community solar projects, the
2623	2623	24 business models of projects, and the size of
2624	2624	25 projects, as described by the Agency in its
2625	2625	26 long-term renewable resources procurement plan
2626	2626
2627	2627
2628	2628
2629	2629
2630	2630
2631	2631	HB5514 - 72 - LRB103 39335 CES 69496 b
2632	2632
2633	2633
2634	2634	HB5514- 73 -LRB103 39335 CES 69496 b HB5514 - 73 - LRB103 39335 CES 69496 b
2635	2635	HB5514 - 73 - LRB103 39335 CES 69496 b
2636	2636	1 that is approved as of the effective date of this
2637	2637	2 amendatory Act of the 102nd General Assembly.
2638	2638	3 Projects in this category shall be subject to the
2639	2639	4 contract terms outlined in item (iii) of
2640	2640	5 subsection (L) of this paragraph (1).
2641	2641	6 (6) The Agency shall open the first blocks of
2642	2642	7 annual capacity for the category described in item
2643	2643	8 (vi) of subparagraph (K) of this paragraph (1),
2644	2644	9 with allocations of capacity within the block
2645	2645	10 generally matching the historical share of block
2646	2646	11 capacity allocated between the category described
2647	2647	12 in items (i) and (ii) of subparagraph (K) of this
2648	2648	13 paragraph (1). The first two blocks of annual
2649	2649	14 capacity for item (vi) shall be for at least 75
2650	2650	15 megawatts of total nameplate capacity. The price
2651	2651	16 of renewable energy credits for the blocks of
2652	2652	17 capacity shall be 4% less than the price of the
2653	2653	18 last open blocks in the categories described in
2654	2654	19 items (i) and (ii) of subparagraph (K) of this
2655	2655	20 paragraph (1). Pricing for future blocks of annual
2656	2656	21 capacity for this category may be adjusted in the
2657	2657	22 Agency's second revision to its Long-Term
2658	2658	23 Renewable Resources Procurement Plan. Projects in
2659	2659	24 this category shall be subject to the applicable
2660	2660	25 contract terms outlined in items (ii) and (iii) of
2661	2661	26 subparagraph (L) of this paragraph (1).
2662	2662
2663	2663
2664	2664
2665	2665
2666	2666
2667	2667	HB5514 - 73 - LRB103 39335 CES 69496 b
2668	2668
2669	2669
2670	2670	HB5514- 74 -LRB103 39335 CES 69496 b HB5514 - 74 - LRB103 39335 CES 69496 b
2671	2671	HB5514 - 74 - LRB103 39335 CES 69496 b
2672	2672	1 (v) Upon the effective date of this amendatory Act
2673	2673	2 of the 102nd General Assembly, for all competitive
2674	2674	3 procurements and any procurements of renewable energy
2675	2675	4 credit from new utility-scale wind and new
2676	2676	5 utility-scale photovoltaic projects, the Agency shall
2677	2677	6 procure indexed renewable energy credits and direct
2678	2678	7 respondents to offer a strike price.
2679	2679	8 (1) The purchase price of the indexed
2680	2680	9 renewable energy credit payment shall be
2681	2681	10 calculated for each settlement period. That
2682	2682	11 payment, for any settlement period, shall be equal
2683	2683	12 to the difference resulting from subtracting the
2684	2684	13 strike price from the index price for that
2685	2685	14 settlement period. If this difference results in a
2686	2686	15 negative number, the indexed REC counterparty
2687	2687	16 shall owe the seller the absolute value multiplied
2688	2688	17 by the quantity of energy produced in the relevant
2689	2689	18 settlement period. If this difference results in a
2690	2690	19 positive number, the seller shall owe the indexed
2691	2691	20 REC counterparty this amount multiplied by the
2692	2692	21 quantity of energy produced in the relevant
2693	2693	22 settlement period.
2694	2694	23 (2) Parties shall cash settle every month,
2695	2695	24 summing up all settlements (both positive and
2696	2696	25 negative, if applicable) for the prior month.
2697	2697	26 (3) To ensure funding in the annual budget
2698	2698
2699	2699
2700	2700
2701	2701
2702	2702
2703	2703	HB5514 - 74 - LRB103 39335 CES 69496 b
2704	2704
2705	2705
2706	2706	HB5514- 75 -LRB103 39335 CES 69496 b HB5514 - 75 - LRB103 39335 CES 69496 b
2707	2707	HB5514 - 75 - LRB103 39335 CES 69496 b
2708	2708	1 established under subparagraph (E) for indexed
2709	2709	2 renewable energy credit procurements for each year
2710	2710	3 of the term of such contracts, which must have a
2711	2711	4 minimum tenure of 20 calendar years, the
2712	2712	5 procurement administrator, Agency, Commission
2713	2713	6 staff, and procurement monitor shall quantify the
2714	2714	7 annual cost of the contract by utilizing an
2715	2715	8 industry-standard, third-party forward price curve
2716	2716	9 for energy at the appropriate hub or load zone,
2717	2717	10 including the estimated magnitude and timing of
2718	2718	11 the price effects related to federal carbon
2719	2719	12 controls. Each forward price curve shall contain a
2720	2720	13 specific value of the forecasted market price of
2721	2721	14 electricity for each annual delivery year of the
2722	2722	15 contract. For procurement planning purposes, the
2723	2723	16 impact on the annual budget for the cost of
2724	2724	17 indexed renewable energy credits for each delivery
2725	2725	18 year shall be determined as the expected annual
2726	2726	19 contract expenditure for that year, equaling the
2727	2727	20 difference between (i) the sum across all relevant
2728	2728	21 contracts of the applicable strike price
2729	2729	22 multiplied by contract quantity and (ii) the sum
2730	2730	23 across all relevant contracts of the forward price
2731	2731	24 curve for the applicable load zone for that year
2732	2732	25 multiplied by contract quantity. The contracting
2733	2733	26 utility shall not assume an obligation in excess
2734	2734
2735	2735
2736	2736
2737	2737
2738	2738
2739	2739	HB5514 - 75 - LRB103 39335 CES 69496 b
2740	2740
2741	2741
2742	2742	HB5514- 76 -LRB103 39335 CES 69496 b HB5514 - 76 - LRB103 39335 CES 69496 b
2743	2743	HB5514 - 76 - LRB103 39335 CES 69496 b
2744	2744	1 of the estimated annual cost of the contracts for
2745	2745	2 indexed renewable energy credits. Forward curves
2746	2746	3 shall be revised on an annual basis as updated
2747	2747	4 forward price curves are released and filed with
2748	2748	5 the Commission in the proceeding approving the
2749	2749	6 Agency's most recent long-term renewable resources
2750	2750	7 procurement plan. If the expected contract spend
2751	2751	8 is higher or lower than the total quantity of
2752	2752	9 contracts multiplied by the forward price curve
2753	2753	10 value for that year, the forward price curve shall
2754	2754	11 be updated by the procurement administrator, in
2755	2755	12 consultation with the Agency, Commission staff,
2756	2756	13 and procurement monitors, using then-currently
2757	2757	14 available price forecast data and additional
2758	2758	15 budget dollars shall be obligated or reobligated
2759	2759	16 as appropriate.
2760	2760	17 (4) To ensure that indexed renewable energy
2761	2761	18 credit prices remain predictable and affordable,
2762	2762	19 the Agency may consider the institution of a price
2763	2763	20 collar on REC prices paid under indexed renewable
2764	2764	21 energy credit procurements establishing floor and
2765	2765	22 ceiling REC prices applicable to indexed REC
2766	2766	23 contract prices. Any price collars applicable to
2767	2767	24 indexed REC procurements shall be proposed by the
2768	2768	25 Agency through its long-term renewable resources
2769	2769	26 procurement plan.
2770	2770
2771	2771
2772	2772
2773	2773
2774	2774
2775	2775	HB5514 - 76 - LRB103 39335 CES 69496 b
2776	2776
2777	2777
2778	2778	HB5514- 77 -LRB103 39335 CES 69496 b HB5514 - 77 - LRB103 39335 CES 69496 b
2779	2779	HB5514 - 77 - LRB103 39335 CES 69496 b
2780	2780	1 (vi) All procurements under this subparagraph (G),
2781	2781	2 including the procurement of renewable energy credits
2782	2782	3 from hydropower facilities, shall comply with the
2783	2783	4 geographic requirements in subparagraph (I) of this
2784	2784	5 paragraph (1) and shall follow the procurement
2785	2785	6 processes and procedures described in this Section and
2786	2786	7 Section 16-111.5 of the Public Utilities Act to the
2787	2787	8 extent practicable, and these processes and procedures
2788	2788	9 may be expedited to accommodate the schedule
2789	2789	10 established by this subparagraph (G).
2790	2790	11 (vii) On and after the effective date of this
2791	2791	12 amendatory Act of the 103rd General Assembly, for all
2792	2792	13 procurements of renewable energy credits from
2793	2793	14 hydropower facilities, the Agency shall establish
2794	2794	15 contract terms designed to optimize existing
2795	2795	16 hydropower facilities through modernization or
2796	2796	17 retooling and establish new hydropower facilities at
2797	2797	18 existing dams. Procurements made under this item (vii)
2798	2798	19 shall prioritize projects located in designated
2799	2799	20 environmental justice communities, as defined in
2800	2800	21 subsection (b) of Section 1-56 of this Act, or in
2801	2801	22 projects located in units of local government with
2802	2802	23 median incomes that do not exceed 82% of the median
2803	2803	24 income of the State.
2804	2804	25 (H) The procurement of renewable energy resources for
2805	2805	26 a given delivery year shall be reduced as described in
2806	2806
2807	2807
2808	2808
2809	2809
2810	2810
2811	2811	HB5514 - 77 - LRB103 39335 CES 69496 b
2812	2812
2813	2813
2814	2814	HB5514- 78 -LRB103 39335 CES 69496 b HB5514 - 78 - LRB103 39335 CES 69496 b
2815	2815	HB5514 - 78 - LRB103 39335 CES 69496 b
2816	2816	1 this subparagraph (H) if an alternative retail electric
2817	2817	2 supplier meets the requirements described in this
2818	2818	3 subparagraph (H).
2819	2819	4 (i) Within 45 days after June 1, 2017 (the
2820	2820	5 effective date of Public Act 99-906), an alternative
2821	2821	6 retail electric supplier or its successor shall submit
2822	2822	7 an informational filing to the Illinois Commerce
2823	2823	8 Commission certifying that, as of December 31, 2015,
2824	2824	9 the alternative retail electric supplier owned one or
2825	2825	10 more electric generating facilities that generates
2826	2826	11 renewable energy resources as defined in Section 1-10
2827	2827	12 of this Act, provided that such facilities are not
2828	2828	13 powered by wind or photovoltaics, and the facilities
2829	2829	14 generate one renewable energy credit for each
2830	2830	15 megawatthour of energy produced from the facility.
2831	2831	16 The informational filing shall identify each
2832	2832	17 facility that was eligible to satisfy the alternative
2833	2833	18 retail electric supplier's obligations under Section
2834	2834	19 16-115D of the Public Utilities Act as described in
2835	2835	20 this item (i).
2836	2836	21 (ii) For a given delivery year, the alternative
2837	2837	22 retail electric supplier may elect to supply its
2838	2838	23 retail customers with renewable energy credits from
2839	2839	24 the facility or facilities described in item (i) of
2840	2840	25 this subparagraph (H) that continue to be owned by the
2841	2841	26 alternative retail electric supplier.
2842	2842
2843	2843
2844	2844
2845	2845
2846	2846
2847	2847	HB5514 - 78 - LRB103 39335 CES 69496 b
2848	2848
2849	2849
2850	2850	HB5514- 79 -LRB103 39335 CES 69496 b HB5514 - 79 - LRB103 39335 CES 69496 b
2851	2851	HB5514 - 79 - LRB103 39335 CES 69496 b
2852	2852	1 (iii) The alternative retail electric supplier
2853	2853	2 shall notify the Agency and the applicable utility, no
2854	2854	3 later than February 28 of the year preceding the
2855	2855	4 applicable delivery year or 15 days after June 1, 2017
2856	2856	5 (the effective date of Public Act 99-906), whichever
2857	2857	6 is later, of its election under item (ii) of this
2858	2858	7 subparagraph (H) to supply renewable energy credits to
2859	2859	8 retail customers of the utility. Such election shall
2860	2860	9 identify the amount of renewable energy credits to be
2861	2861	10 supplied by the alternative retail electric supplier
2862	2862	11 to the utility's retail customers and the source of
2863	2863	12 the renewable energy credits identified in the
2864	2864	13 informational filing as described in item (i) of this
2865	2865	14 subparagraph (H), subject to the following
2866	2866	15 limitations:
2867	2867	16 For the delivery year beginning June 1, 2018,
2868	2868	17 the maximum amount of renewable energy credits to
2869	2869	18 be supplied by an alternative retail electric
2870	2870	19 supplier under this subparagraph (H) shall be 68%
2871	2871	20 multiplied by 25% multiplied by 14.5% multiplied
2872	2872	21 by the amount of metered electricity
2873	2873	22 (megawatt-hours) delivered by the alternative
2874	2874	23 retail electric supplier to Illinois retail
2875	2875	24 customers during the delivery year ending May 31,
2876	2876	25 2016.
2877	2877	26 For delivery years beginning June 1, 2019 and
2878	2878
2879	2879
2880	2880
2881	2881
2882	2882
2883	2883	HB5514 - 79 - LRB103 39335 CES 69496 b
2884	2884
2885	2885
2886	2886	HB5514- 80 -LRB103 39335 CES 69496 b HB5514 - 80 - LRB103 39335 CES 69496 b
2887	2887	HB5514 - 80 - LRB103 39335 CES 69496 b
2888	2888	1 each year thereafter, the maximum amount of
2889	2889	2 renewable energy credits to be supplied by an
2890	2890	3 alternative retail electric supplier under this
2891	2891	4 subparagraph (H) shall be 68% multiplied by 50%
2892	2892	5 multiplied by 16% multiplied by the amount of
2893	2893	6 metered electricity (megawatt-hours) delivered by
2894	2894	7 the alternative retail electric supplier to
2895	2895	8 Illinois retail customers during the delivery year
2896	2896	9 ending May 31, 2016, provided that the 16% value
2897	2897	10 shall increase by 1.5% each delivery year
2898	2898	11 thereafter to 25% by the delivery year beginning
2899	2899	12 June 1, 2025, and thereafter the 25% value shall
2900	2900	13 apply to each delivery year.
2901	2901	14 For each delivery year, the total amount of
2902	2902	15 renewable energy credits supplied by all alternative
2903	2903	16 retail electric suppliers under this subparagraph (H)
2904	2904	17 shall not exceed 9% of the Illinois target renewable
2905	2905	18 energy credit quantity. The Illinois target renewable
2906	2906	19 energy credit quantity for the delivery year beginning
2907	2907	20 June 1, 2018 is 14.5% multiplied by the total amount of
2908	2908	21 metered electricity (megawatt-hours) delivered in the
2909	2909	22 delivery year immediately preceding that delivery
2910	2910	23 year, provided that the 14.5% shall increase by 1.5%
2911	2911	24 each delivery year thereafter to 25% by the delivery
2912	2912	25 year beginning June 1, 2025, and thereafter the 25%
2913	2913	26 value shall apply to each delivery year.
2914	2914
2915	2915
2916	2916
2917	2917
2918	2918
2919	2919	HB5514 - 80 - LRB103 39335 CES 69496 b
2920	2920
2921	2921
2922	2922	HB5514- 81 -LRB103 39335 CES 69496 b HB5514 - 81 - LRB103 39335 CES 69496 b
2923	2923	HB5514 - 81 - LRB103 39335 CES 69496 b
2924	2924	1 If the requirements set forth in items (i) through
2925	2925	2 (iii) of this subparagraph (H) are met, the charges
2926	2926	3 that would otherwise be applicable to the retail
2927	2927	4 customers of the alternative retail electric supplier
2928	2928	5 under paragraph (6) of this subsection (c) for the
2929	2929	6 applicable delivery year shall be reduced by the ratio
2930	2930	7 of the quantity of renewable energy credits supplied
2931	2931	8 by the alternative retail electric supplier compared
2932	2932	9 to that supplier's target renewable energy credit
2933	2933	10 quantity. The supplier's target renewable energy
2934	2934	11 credit quantity for the delivery year beginning June
2935	2935	12 1, 2018 is 14.5% multiplied by the total amount of
2936	2936	13 metered electricity (megawatt-hours) delivered by the
2937	2937	14 alternative retail supplier in that delivery year,
2938	2938	15 provided that the 14.5% shall increase by 1.5% each
2939	2939	16 delivery year thereafter to 25% by the delivery year
2940	2940	17 beginning June 1, 2025, and thereafter the 25% value
2941	2941	18 shall apply to each delivery year.
2942	2942	19 On or before April 1 of each year, the Agency shall
2943	2943	20 annually publish a report on its website that
2944	2944	21 identifies the aggregate amount of renewable energy
2945	2945	22 credits supplied by alternative retail electric
2946	2946	23 suppliers under this subparagraph (H).
2947	2947	24 (I) The Agency shall design its long-term renewable
2948	2948	25 energy procurement plan to maximize the State's interest
2949	2949	26 in the health, safety, and welfare of its residents,
2950	2950
2951	2951
2952	2952
2953	2953
2954	2954
2955	2955	HB5514 - 81 - LRB103 39335 CES 69496 b
2956	2956
2957	2957
2958	2958	HB5514- 82 -LRB103 39335 CES 69496 b HB5514 - 82 - LRB103 39335 CES 69496 b
2959	2959	HB5514 - 82 - LRB103 39335 CES 69496 b
2960	2960	1 including but not limited to minimizing sulfur dioxide,
2961	2961	2 nitrogen oxide, particulate matter and other pollution
2962	2962	3 that adversely affects public health in this State,
2963	2963	4 increasing fuel and resource diversity in this State,
2964	2964	5 enhancing the reliability and resiliency of the
2965	2965	6 electricity distribution system in this State, meeting
2966	2966	7 goals to limit carbon dioxide emissions under federal or
2967	2967	8 State law, and contributing to a cleaner and healthier
2968	2968	9 environment for the citizens of this State. In order to
2969	2969	10 further these legislative purposes, renewable energy
2970	2970	11 credits shall be eligible to be counted toward the
2971	2971	12 renewable energy requirements of this subsection (c) if
2972	2972	13 they are generated from facilities located in this State.
2973	2973	14 The Agency may qualify renewable energy credits from
2974	2974	15 facilities located in states adjacent to Illinois or
2975	2975	16 renewable energy credits associated with the electricity
2976	2976	17 generated by a utility-scale wind energy facility or
2977	2977	18 utility-scale photovoltaic facility and transmitted by a
2978	2978	19 qualifying direct current project described in subsection
2979	2979	20 (b-5) of Section 8-406 of the Public Utilities Act to a
2980	2980	21 delivery point on the electric transmission grid located
2981	2981	22 in this State or a state adjacent to Illinois, if the
2982	2982	23 generator demonstrates and the Agency determines that the
2983	2983	24 operation of such facility or facilities will help promote
2984	2984	25 the State's interest in the health, safety, and welfare of
2985	2985	26 its residents based on the public interest criteria
2986	2986
2987	2987
2988	2988
2989	2989
2990	2990
2991	2991	HB5514 - 82 - LRB103 39335 CES 69496 b
2992	2992
2993	2993
2994	2994	HB5514- 83 -LRB103 39335 CES 69496 b HB5514 - 83 - LRB103 39335 CES 69496 b
2995	2995	HB5514 - 83 - LRB103 39335 CES 69496 b
2996	2996	1 described above. For the purposes of this Section,
2997	2997	2 renewable resources that are delivered via a high voltage
2998	2998	3 direct current converter station located in Illinois shall
2999	2999	4 be deemed generated in Illinois at the time and location
3000	3000	5 the energy is converted to alternating current by the high
3001	3001	6 voltage direct current converter station if the high
3002	3002	7 voltage direct current transmission line: (i) after the
3003	3003	8 effective date of this amendatory Act of the 102nd General
3004	3004	9 Assembly, was constructed with a project labor agreement;
3005	3005	10 (ii) is capable of transmitting electricity at 525kv;
3006	3006	11 (iii) has an Illinois converter station located and
3007	3007	12 interconnected in the region of the PJM Interconnection,
3008	3008	13 LLC; (iv) does not operate as a public utility; and (v) if
3009	3009	14 the high voltage direct current transmission line was
3010	3010	15 energized after June 1, 2023. To ensure that the public
3011	3011	16 interest criteria are applied to the procurement and given
3012	3012	17 full effect, the Agency's long-term procurement plan shall
3013	3013	18 describe in detail how each public interest factor shall
3014	3014	19 be considered and weighted for facilities located in
3015	3015	20 states adjacent to Illinois.
3016	3016	21 (J) In order to promote the competitive development of
3017	3017	22 renewable energy resources in furtherance of the State's
3018	3018	23 interest in the health, safety, and welfare of its
3019	3019	24 residents, renewable energy credits shall not be eligible
3020	3020	25 to be counted toward the renewable energy requirements of
3021	3021	26 this subsection (c) if they are sourced from a generating
3022	3022
3023	3023
3024	3024
3025	3025
3026	3026
3027	3027	HB5514 - 83 - LRB103 39335 CES 69496 b
3028	3028
3029	3029
3030	3030	HB5514- 84 -LRB103 39335 CES 69496 b HB5514 - 84 - LRB103 39335 CES 69496 b
3031	3031	HB5514 - 84 - LRB103 39335 CES 69496 b
3032	3032	1 unit whose costs were being recovered through rates
3033	3033	2 regulated by this State or any other state or states on or
3034	3034	3 after January 1, 2017. Each contract executed to purchase
3035	3035	4 renewable energy credits under this subsection (c) shall
3036	3036	5 provide for the contract's termination if the costs of the
3037	3037	6 generating unit supplying the renewable energy credits
3038	3038	7 subsequently begin to be recovered through rates regulated
3039	3039	8 by this State or any other state or states; and each
3040	3040	9 contract shall further provide that, in that event, the
3041	3041	10 supplier of the credits must return 110% of all payments
3042	3042	11 received under the contract. Amounts returned under the
3043	3043	12 requirements of this subparagraph (J) shall be retained by
3044	3044	13 the utility and all of these amounts shall be used for the
3045	3045	14 procurement of additional renewable energy credits from
3046	3046	15 new wind or new photovoltaic resources as defined in this
3047	3047	16 subsection (c). The long-term plan shall provide that
3048	3048	17 these renewable energy credits shall be procured in the
3049	3049	18 next procurement event.
3050	3050	19 Notwithstanding the limitations of this subparagraph
3051	3051	20 (J), renewable energy credits sourced from generating
3052	3052	21 units that are constructed, purchased, owned, or leased by
3053	3053	22 an electric utility as part of an approved project,
3054	3054	23 program, or pilot under Section 1-56 of this Act shall be
3055	3055	24 eligible to be counted toward the renewable energy
3056	3056	25 requirements of this subsection (c), regardless of how the
3057	3057	26 costs of these units are recovered. As long as a
3058	3058
3059	3059
3060	3060
3061	3061
3062	3062
3063	3063	HB5514 - 84 - LRB103 39335 CES 69496 b
3064	3064
3065	3065
3066	3066	HB5514- 85 -LRB103 39335 CES 69496 b HB5514 - 85 - LRB103 39335 CES 69496 b
3067	3067	HB5514 - 85 - LRB103 39335 CES 69496 b
3068	3068	1 generating unit or an identifiable portion of a generating
3069	3069	2 unit has not had and does not have its costs recovered
3070	3070	3 through rates regulated by this State or any other state,
3071	3071	4 HVDC renewable energy credits associated with that
3072	3072	5 generating unit or identifiable portion thereof shall be
3073	3073	6 eligible to be counted toward the renewable energy
3074	3074	7 requirements of this subsection (c).
3075	3075	8 (K) The long-term renewable resources procurement plan
3076	3076	9 developed by the Agency in accordance with subparagraph
3077	3077	10 (A) of this paragraph (1) shall include an Adjustable
3078	3078	11 Block program for the procurement of renewable energy
3079	3079	12 credits from new photovoltaic projects that are
3080	3080	13 distributed renewable energy generation devices or new
3081	3081	14 photovoltaic community renewable generation projects. The
3082	3082	15 Adjustable Block program shall be generally designed to
3083	3083	16 provide for the steady, predictable, and sustainable
3084	3084	17 growth of new solar photovoltaic development in Illinois.
3085	3085	18 To this end, the Adjustable Block program shall provide a
3086	3086	19 transparent annual schedule of prices and quantities to
3087	3087	20 enable the photovoltaic market to scale up and for
3088	3088	21 renewable energy credit prices to adjust at a predictable
3089	3089	22 rate over time. The prices set by the Adjustable Block
3090	3090	23 program can be reflected as a set value or as the product
3091	3091	24 of a formula.
3092	3092	25 The Adjustable Block program shall include for each
3093	3093	26 category of eligible projects for each delivery year: a
3094	3094
3095	3095
3096	3096
3097	3097
3098	3098
3099	3099	HB5514 - 85 - LRB103 39335 CES 69496 b
3100	3100
3101	3101
3102	3102	HB5514- 86 -LRB103 39335 CES 69496 b HB5514 - 86 - LRB103 39335 CES 69496 b
3103	3103	HB5514 - 86 - LRB103 39335 CES 69496 b
3104	3104	1 single block of nameplate capacity, a price for renewable
3105	3105	2 energy credits within that block, and the terms and
3106	3106	3 conditions for securing a spot on a waitlist once the
3107	3107	4 block is fully committed or reserved. Except as outlined
3108	3108	5 below, the waitlist of projects in a given year will carry
3109	3109	6 over to apply to the subsequent year when another block is
3110	3110	7 opened. Only projects energized on or after June 1, 2017
3111	3111	8 shall be eligible for the Adjustable Block program. For
3112	3112	9 each category for each delivery year the Agency shall
3113	3113	10 determine the amount of generation capacity in each block,
3114	3114	11 and the purchase price for each block, provided that the
3115	3115	12 purchase price provided and the total amount of generation
3116	3116	13 in all blocks for all categories shall be sufficient to
3117	3117	14 meet the goals in this subsection (c). The Agency shall
3118	3118	15 strive to issue a single block sized to provide for
3119	3119	16 stability and market growth. The Agency shall establish
3120	3120	17 program eligibility requirements that ensure that projects
3121	3121	18 that enter the program are sufficiently mature to indicate
3122	3122	19 a demonstrable path to completion. The Agency may
3123	3123	20 periodically review its prior decisions establishing the
3124	3124	21 amount of generation capacity in each block, and the
3125	3125	22 purchase price for each block, and may propose, on an
3126	3126	23 expedited basis, changes to these previously set values,
3127	3127	24 including but not limited to redistributing these amounts
3128	3128	25 and the available funds as necessary and appropriate,
3129	3129	26 subject to Commission approval as part of the periodic
3130	3130
3131	3131
3132	3132
3133	3133
3134	3134
3135	3135	HB5514 - 86 - LRB103 39335 CES 69496 b
3136	3136
3137	3137
3138	3138	HB5514- 87 -LRB103 39335 CES 69496 b HB5514 - 87 - LRB103 39335 CES 69496 b
3139	3139	HB5514 - 87 - LRB103 39335 CES 69496 b
3140	3140	1 plan revision process described in Section 16-111.5 of the
3141	3141	2 Public Utilities Act. The Agency may define different
3142	3142	3 block sizes, purchase prices, or other distinct terms and
3143	3143	4 conditions for projects located in different utility
3144	3144	5 service territories if the Agency deems it necessary to
3145	3145	6 meet the goals in this subsection (c).
3146	3146	7 The Adjustable Block program shall include the
3147	3147	8 following categories in at least the following amounts:
3148	3148	9 (i) At least 20% from distributed renewable energy
3149	3149	10 generation devices with a nameplate capacity of no
3150	3150	11 more than 25 kilowatts.
3151	3151	12 (ii) At least 20% from distributed renewable
3152	3152	13 energy generation devices with a nameplate capacity of
3153	3153	14 more than 25 kilowatts and no more than 5,000
3154	3154	15 kilowatts. The Agency may create sub-categories within
3155	3155	16 this category to account for the differences between
3156	3156	17 projects for small commercial customers, large
3157	3157	18 commercial customers, and public or non-profit
3158	3158	19 customers.
3159	3159	20 (iii) At least 30% from photovoltaic community
3160	3160	21 renewable generation projects. Capacity for this
3161	3161	22 category for the first 2 delivery years after the
3162	3162	23 effective date of this amendatory Act of the 102nd
3163	3163	24 General Assembly shall be allocated to waitlist
3164	3164	25 projects as provided in paragraph (3) of item (iv) of
3165	3165	26 subparagraph (G). Starting in the third delivery year
3166	3166
3167	3167
3168	3168
3169	3169
3170	3170
3171	3171	HB5514 - 87 - LRB103 39335 CES 69496 b
3172	3172
3173	3173
3174	3174	HB5514- 88 -LRB103 39335 CES 69496 b HB5514 - 88 - LRB103 39335 CES 69496 b
3175	3175	HB5514 - 88 - LRB103 39335 CES 69496 b
3176	3176	1 after the effective date of this amendatory Act of the
3177	3177	2 102nd General Assembly or earlier if the Agency
3178	3178	3 determines there is additional capacity needed for to
3179	3179	4 meet previous delivery year requirements, the
3180	3180	5 following shall apply:
3181	3181	6 (1) the Agency shall select projects on a
3182	3182	7 first-come, first-serve basis, however the Agency
3183	3183	8 may suggest additional methods to prioritize
3184	3184	9 projects that are submitted at the same time;
3185	3185	10 (2) projects shall have subscriptions of 25 kW
3186	3186	11 or less for at least 50% of the facility's
3187	3187	12 nameplate capacity and the Agency shall price the
3188	3188	13 renewable energy credits with that as a factor;
3189	3189	14 (3) projects shall not be colocated with one
3190	3190	15 or more other community renewable generation
3191	3191	16 projects, as defined in the Agency's first revised
3192	3192	17 long-term renewable resources procurement plan
3193	3193	18 approved by the Commission on February 18, 2020,
3194	3194	19 such that the aggregate nameplate capacity exceeds
3195	3195	20 5,000 kilowatts; and
3196	3196	21 (4) projects greater than 2 MW may not apply
3197	3197	22 until after the approval of the Agency's revised
3198	3198	23 Long-Term Renewable Resources Procurement Plan
3199	3199	24 after the effective date of this amendatory Act of
3200	3200	25 the 102nd General Assembly.
3201	3201	26 (iv) At least 15% from distributed renewable
3202	3202
3203	3203
3204	3204
3205	3205
3206	3206
3207	3207	HB5514 - 88 - LRB103 39335 CES 69496 b
3208	3208
3209	3209
3210	3210	HB5514- 89 -LRB103 39335 CES 69496 b HB5514 - 89 - LRB103 39335 CES 69496 b
3211	3211	HB5514 - 89 - LRB103 39335 CES 69496 b
3212	3212	1 generation devices or photovoltaic community renewable
3213	3213	2 generation projects installed on public school land.
3214	3214	3 The Agency may create subcategories within this
3215	3215	4 category to account for the differences between
3216	3216	5 project size or location. Projects located within
3217	3217	6 environmental justice communities or within
3218	3218	7 Organizational Units that fall within Tier 1 or Tier 2
3219	3219	8 shall be given priority. Each of the Agency's periodic
3220	3220	9 updates to its long-term renewable resources
3221	3221	10 procurement plan to incorporate the procurement
3222	3222	11 described in this subparagraph (iv) shall also include
3223	3223	12 the proposed quantities or blocks, pricing, and
3224	3224	13 contract terms applicable to the procurement as
3225	3225	14 indicated herein. In each such update and procurement,
3226	3226	15 the Agency shall set the renewable energy credit price
3227	3227	16 and establish payment terms for the renewable energy
3228	3228	17 credits procured pursuant to this subparagraph (iv)
3229	3229	18 that make it feasible and affordable for public
3230	3230	19 schools to install photovoltaic distributed renewable
3231	3231	20 energy devices on their premises, including, but not
3232	3232	21 limited to, those public schools subject to the
3233	3233	22 prioritization provisions of this subparagraph. For
3234	3234	23 the purposes of this item (iv):
3235	3235	24 "Environmental Justice Community" shall have the
3236	3236	25 same meaning set forth in the Agency's long-term
3237	3237	26 renewable resources procurement plan;
3238	3238
3239	3239
3240	3240
3241	3241
3242	3242
3243	3243	HB5514 - 89 - LRB103 39335 CES 69496 b
3244	3244
3245	3245
3246	3246	HB5514- 90 -LRB103 39335 CES 69496 b HB5514 - 90 - LRB103 39335 CES 69496 b
3247	3247	HB5514 - 90 - LRB103 39335 CES 69496 b
3248	3248	1 "Organization Unit", "Tier 1" and "Tier 2" shall
3249	3249	2 have the meanings set for in Section 18-8.15 of the
3250	3250	3 School Code;
3251	3251	4 "Public schools" shall have the meaning set forth
3252	3252	5 in Section 1-3 of the School Code and includes public
3253	3253	6 institutions of higher education, as defined in the
3254	3254	7 Board of Higher Education Act.
3255	3255	8 (v) At least 5% from community-driven community
3256	3256	9 solar projects intended to provide more direct and
3257	3257	10 tangible connection and benefits to the communities
3258	3258	11 which they serve or in which they operate and,
3259	3259	12 additionally, to increase the variety of community
3260	3260	13 solar locations, models, and options in Illinois. As
3261	3261	14 part of its long-term renewable resources procurement
3262	3262	15 plan, the Agency shall develop selection criteria for
3263	3263	16 projects participating in this category. Nothing in
3264	3264	17 this Section shall preclude the Agency from creating a
3265	3265	18 selection process that maximizes community ownership
3266	3266	19 and community benefits in selecting projects to
3267	3267	20 receive renewable energy credits. Selection criteria
3268	3268	21 shall include:
3269	3269	22 (1) community ownership or community
3270	3270	23 wealth-building;
3271	3271	24 (2) additional direct and indirect community
3272	3272	25 benefit, beyond project participation as a
3273	3273	26 subscriber, including, but not limited to,
3274	3274
3275	3275
3276	3276
3277	3277
3278	3278
3279	3279	HB5514 - 90 - LRB103 39335 CES 69496 b
3280	3280
3281	3281
3282	3282	HB5514- 91 -LRB103 39335 CES 69496 b HB5514 - 91 - LRB103 39335 CES 69496 b
3283	3283	HB5514 - 91 - LRB103 39335 CES 69496 b
3284	3284	1 economic, environmental, social, cultural, and
3285	3285	2 physical benefits;
3286	3286	3 (3) meaningful involvement in project
3287	3287	4 organization and development by community members
3288	3288	5 or nonprofit organizations or public entities
3289	3289	6 located in or serving the community;
3290	3290	7 (4) engagement in project operations and
3291	3291	8 management by nonprofit organizations, public
3292	3292	9 entities, or community members; and
3293	3293	10 (5) whether a project is developed in response
3294	3294	11 to a site-specific RFP developed by community
3295	3295	12 members or a nonprofit organization or public
3296	3296	13 entity located in or serving the community.
3297	3297	14 Selection criteria may also prioritize projects
3298	3298	15 that:
3299	3299	16 (1) are developed in collaboration with or to
3300	3300	17 provide complementary opportunities for the Clean
3301	3301	18 Jobs Workforce Network Program, the Illinois
3302	3302	19 Climate Works Preapprenticeship Program, the
3303	3303	20 Returning Residents Clean Jobs Training Program,
3304	3304	21 the Clean Energy Contractor Incubator Program, or
3305	3305	22 the Clean Energy Primes Contractor Accelerator
3306	3306	23 Program;
3307	3307	24 (2) increase the diversity of locations of
3308	3308	25 community solar projects in Illinois, including by
3309	3309	26 locating in urban areas and population centers;
3310	3310
3311	3311
3312	3312
3313	3313
3314	3314
3315	3315	HB5514 - 91 - LRB103 39335 CES 69496 b
3316	3316
3317	3317
3318	3318	HB5514- 92 -LRB103 39335 CES 69496 b HB5514 - 92 - LRB103 39335 CES 69496 b
3319	3319	HB5514 - 92 - LRB103 39335 CES 69496 b
3320	3320	1 (3) are located in Equity Investment Eligible
3321	3321	2 Communities;
3322	3322	3 (4) are not greenfield projects;
3323	3323	4 (5) serve only local subscribers;
3324	3324	5 (6) have a nameplate capacity that does not
3325	3325	6 exceed 500 kW;
3326	3326	7 (7) are developed by an equity eligible
3327	3327	8 contractor; or
3328	3328	9 (8) otherwise meaningfully advance the goals
3329	3329	10 of providing more direct and tangible connection
3330	3330	11 and benefits to the communities which they serve
3331	3331	12 or in which they operate and increasing the
3332	3332	13 variety of community solar locations, models, and
3333	3333	14 options in Illinois.
3334	3334	15 For the purposes of this item (v):
3335	3335	16 "Community" means a social unit in which people
3336	3336	17 come together regularly to effect change; a social
3337	3337	18 unit in which participants are marked by a cooperative
3338	3338	19 spirit, a common purpose, or shared interests or
3339	3339	20 characteristics; or a space understood by its
3340	3340	21 residents to be delineated through geographic
3341	3341	22 boundaries or landmarks.
3342	3342	23 "Community benefit" means a range of services and
3343	3343	24 activities that provide affirmative, economic,
3344	3344	25 environmental, social, cultural, or physical value to
3345	3345	26 a community; or a mechanism that enables economic
3346	3346
3347	3347
3348	3348
3349	3349
3350	3350
3351	3351	HB5514 - 92 - LRB103 39335 CES 69496 b
3352	3352
3353	3353
3354	3354	HB5514- 93 -LRB103 39335 CES 69496 b HB5514 - 93 - LRB103 39335 CES 69496 b
3355	3355	HB5514 - 93 - LRB103 39335 CES 69496 b
3356	3356	1 development, high-quality employment, and education
3357	3357	2 opportunities for local workers and residents, or
3358	3358	3 formal monitoring and oversight structures such that
3359	3359	4 community members may ensure that those services and
3360	3360	5 activities respond to local knowledge and needs.
3361	3361	6 "Community ownership" means an arrangement in
3362	3362	7 which an electric generating facility is, or over time
3363	3363	8 will be, in significant part, owned collectively by
3364	3364	9 members of the community to which an electric
3365	3365	10 generating facility provides benefits; members of that
3366	3366	11 community participate in decisions regarding the
3367	3367	12 governance, operation, maintenance, and upgrades of
3368	3368	13 and to that facility; and members of that community
3369	3369	14 benefit from regular use of that facility.
3370	3370	15 Terms and guidance within these criteria that are
3371	3371	16 not defined in this item (v) shall be defined by the
3372	3372	17 Agency, with stakeholder input, during the development
3373	3373	18 of the Agency's long-term renewable resources
3374	3374	19 procurement plan. The Agency shall develop regular
3375	3375	20 opportunities for projects to submit applications for
3376	3376	21 projects under this category, and develop selection
3377	3377	22 criteria that gives preference to projects that better
3378	3378	23 meet individual criteria as well as projects that
3379	3379	24 address a higher number of criteria.
3380	3380	25 (vi) At least 10% from distributed renewable
3381	3381	26 energy generation devices, which includes distributed
3382	3382
3383	3383
3384	3384
3385	3385
3386	3386
3387	3387	HB5514 - 93 - LRB103 39335 CES 69496 b
3388	3388
3389	3389
3390	3390	HB5514- 94 -LRB103 39335 CES 69496 b HB5514 - 94 - LRB103 39335 CES 69496 b
3391	3391	HB5514 - 94 - LRB103 39335 CES 69496 b
3392	3392	1 renewable energy devices with a nameplate capacity
3393	3393	2 under 5,000 kilowatts or photovoltaic community
3394	3394	3 renewable generation projects, from applicants that
3395	3395	4 are equity eligible contractors. The Agency may create
3396	3396	5 subcategories within this category to account for the
3397	3397	6 differences between project size and type. The Agency
3398	3398	7 shall propose to increase the percentage in this item
3399	3399	8 (vi) over time to 40% based on factors, including, but
3400	3400	9 not limited to, the number of equity eligible
3401	3401	10 contractors and capacity used in this item (vi) in
3402	3402	11 previous delivery years.
3403	3403	12 The Agency shall propose a payment structure for
3404	3404	13 contracts executed pursuant to this paragraph under
3405	3405	14 which, upon a demonstration of qualification or need,
3406	3406	15 applicant firms are advanced capital disbursed after
3407	3407	16 contract execution but before the contracted project's
3408	3408	17 energization. The amount or percentage of capital
3409	3409	18 advanced prior to project energization shall be
3410	3410	19 sufficient to both cover any increase in development
3411	3411	20 costs resulting from prevailing wage requirements or
3412	3412	21 project-labor agreements, and designed to overcome
3413	3413	22 barriers in access to capital faced by equity eligible
3414	3414	23 contractors. The amount or percentage of advanced
3415	3415	24 capital may vary by subcategory within this category
3416	3416	25 and by an applicant's demonstration of need, with such
3417	3417	26 levels to be established through the Long-Term
3418	3418
3419	3419
3420	3420
3421	3421
3422	3422
3423	3423	HB5514 - 94 - LRB103 39335 CES 69496 b
3424	3424
3425	3425
3426	3426	HB5514- 95 -LRB103 39335 CES 69496 b HB5514 - 95 - LRB103 39335 CES 69496 b
3427	3427	HB5514 - 95 - LRB103 39335 CES 69496 b
3428	3428	1 Renewable Resources Procurement Plan authorized under
3429	3429	2 subparagraph (A) of paragraph (1) of subsection (c) of
3430	3430	3 this Section.
3431	3431	4 Contracts developed featuring capital advanced
3432	3432	5 prior to a project's energization shall feature
3433	3433	6 provisions to ensure both the successful development
3434	3434	7 of applicant projects and the delivery of the
3435	3435	8 renewable energy credits for the full term of the
3436	3436	9 contract, including ongoing collateral requirements
3437	3437	10 and other provisions deemed necessary by the Agency,
3438	3438	11 and may include energization timelines longer than for
3439	3439	12 comparable project types. The percentage or amount of
3440	3440	13 capital advanced prior to project energization shall
3441	3441	14 not operate to increase the overall contract value,
3442	3442	15 however contracts executed under this subparagraph may
3443	3443	16 feature renewable energy credit prices higher than
3444	3444	17 those offered to similar projects participating in
3445	3445	18 other categories. Capital advanced prior to
3446	3446	19 energization shall serve to reduce the ratable
3447	3447	20 payments made after energization under items (ii) and
3448	3448	21 (iii) of subparagraph (L) or payments made for each
3449	3449	22 renewable energy credit delivery under item (iv) of
3450	3450	23 subparagraph (L).
3451	3451	24 (vii) The remaining capacity shall be allocated by
3452	3452	25 the Agency in order to respond to market demand. The
3453	3453	26 Agency shall allocate any discretionary capacity prior
3454	3454
3455	3455
3456	3456
3457	3457
3458	3458
3459	3459	HB5514 - 95 - LRB103 39335 CES 69496 b
3460	3460
3461	3461
3462	3462	HB5514- 96 -LRB103 39335 CES 69496 b HB5514 - 96 - LRB103 39335 CES 69496 b
3463	3463	HB5514 - 96 - LRB103 39335 CES 69496 b
3464	3464	1 to the beginning of each delivery year.
3465	3465	2 To the extent there is uncontracted capacity from any
3466	3466	3 block in any of categories (i) through (vi) at the end of a
3467	3467	4 delivery year, the Agency shall redistribute that capacity
3468	3468	5 to one or more other categories giving priority to
3469	3469	6 categories with projects on a waitlist. The redistributed
3470	3470	7 capacity shall be added to the annual capacity in the
3471	3471	8 subsequent delivery year, and the price for renewable
3472	3472	9 energy credits shall be the price for the new delivery
3473	3473	10 year. Redistributed capacity shall not be considered
3474	3474	11 redistributed when determining whether the goals in this
3475	3475	12 subsection (K) have been met.
3476	3476	13 Notwithstanding anything to the contrary, as the
3477	3477	14 Agency increases the capacity in item (vi) to 40% over
3478	3478	15 time, the Agency may reduce the capacity of items (i)
3479	3479	16 through (v) proportionate to the capacity of the
3480	3480	17 categories of projects in item (vi), to achieve a balance
3481	3481	18 of project types.
3482	3482	19 The Adjustable Block program shall be designed to
3483	3483	20 ensure that renewable energy credits are procured from
3484	3484	21 projects in diverse locations and are not concentrated in
3485	3485	22 a few regional areas.
3486	3486	23 (L) Notwithstanding provisions for advancing capital
3487	3487	24 prior to project energization found in item (vi) of
3488	3488	25 subparagraph (K), the procurement of photovoltaic
3489	3489	26 renewable energy credits under items (i) through (vi) of
3490	3490
3491	3491
3492	3492
3493	3493
3494	3494
3495	3495	HB5514 - 96 - LRB103 39335 CES 69496 b
3496	3496
3497	3497
3498	3498	HB5514- 97 -LRB103 39335 CES 69496 b HB5514 - 97 - LRB103 39335 CES 69496 b
3499	3499	HB5514 - 97 - LRB103 39335 CES 69496 b
3500	3500	1 subparagraph (K) of this paragraph (1) shall otherwise be
3501	3501	2 subject to the following contract and payment terms:
3502	3502	3 (i) (Blank).
3503	3503	4 (ii) For those renewable energy credits that
3504	3504	5 qualify and are procured under item (i) of
3505	3505	6 subparagraph (K) of this paragraph (1), and any
3506	3506	7 similar category projects that are procured under item
3507	3507	8 (vi) of subparagraph (K) of this paragraph (1) that
3508	3508	9 qualify and are procured under item (vi), the contract
3509	3509	10 length shall be 15 years. The renewable energy credit
3510	3510	11 delivery contract value shall be paid in full, based
3511	3511	12 on the estimated generation during the first 15 years
3512	3512	13 of operation, by the contracting utilities at the time
3513	3513	14 that the facility producing the renewable energy
3514	3514	15 credits is interconnected at the distribution system
3515	3515	16 level of the utility and verified as energized and
3516	3516	17 compliant by the Program Administrator. The electric
3517	3517	18 utility shall receive and retire all renewable energy
3518	3518	19 credits generated by the project for the first 15
3519	3519	20 years of operation. Renewable energy credits generated
3520	3520	21 by the project thereafter shall not be transferred
3521	3521	22 under the renewable energy credit delivery contract
3522	3522	23 with the counterparty electric utility.
3523	3523	24 (iii) For those renewable energy credits that
3524	3524	25 qualify and are procured under item (ii) and (v) of
3525	3525	26 subparagraph (K) of this paragraph (1) and any like
3526	3526
3527	3527
3528	3528
3529	3529
3530	3530
3531	3531	HB5514 - 97 - LRB103 39335 CES 69496 b
3532	3532
3533	3533
3534	3534	HB5514- 98 -LRB103 39335 CES 69496 b HB5514 - 98 - LRB103 39335 CES 69496 b
3535	3535	HB5514 - 98 - LRB103 39335 CES 69496 b
3536	3536	1 projects similar category that qualify and are
3537	3537	2 procured under item (vi), the contract length shall be
3538	3538	3 15 years. 15% of the renewable energy credit delivery
3539	3539	4 contract value, based on the estimated generation
3540	3540	5 during the first 15 years of operation, shall be paid
3541	3541	6 by the contracting utilities at the time that the
3542	3542	7 facility producing the renewable energy credits is
3543	3543	8 interconnected at the distribution system level of the
3544	3544	9 utility and verified as energized and compliant by the
3545	3545	10 Program Administrator. The remaining portion shall be
3546	3546	11 paid ratably over the subsequent 6-year period. The
3547	3547	12 electric utility shall receive and retire all
3548	3548	13 renewable energy credits generated by the project for
3549	3549	14 the first 15 years of operation. Renewable energy
3550	3550	15 credits generated by the project thereafter shall not
3551	3551	16 be transferred under the renewable energy credit
3552	3552	17 delivery contract with the counterparty electric
3553	3553	18 utility.
3554	3554	19 (iv) For those renewable energy credits that
3555	3555	20 qualify and are procured under items (iii) and (iv) of
3556	3556	21 subparagraph (K) of this paragraph (1), and any like
3557	3557	22 projects that qualify and are procured under item
3558	3558	23 (vi), the renewable energy credit delivery contract
3559	3559	24 length shall be 20 years and shall be paid over the
3560	3560	25 delivery term, not to exceed during each delivery year
3561	3561	26 the contract price multiplied by the estimated annual
3562	3562
3563	3563
3564	3564
3565	3565
3566	3566
3567	3567	HB5514 - 98 - LRB103 39335 CES 69496 b
3568	3568
3569	3569
3570	3570	HB5514- 99 -LRB103 39335 CES 69496 b HB5514 - 99 - LRB103 39335 CES 69496 b
3571	3571	HB5514 - 99 - LRB103 39335 CES 69496 b
3572	3572	1 renewable energy credit generation amount. If
3573	3573	2 generation of renewable energy credits during a
3574	3574	3 delivery year exceeds the estimated annual generation
3575	3575	4 amount, the excess renewable energy credits shall be
3576	3576	5 carried forward to future delivery years and shall not
3577	3577	6 expire during the delivery term. If generation of
3578	3578	7 renewable energy credits during a delivery year,
3579	3579	8 including carried forward excess renewable energy
3580	3580	9 credits, if any, is less than the estimated annual
3581	3581	10 generation amount, payments during such delivery year
3582	3582	11 will not exceed the quantity generated plus the
3583	3583	12 quantity carried forward multiplied by the contract
3584	3584	13 price. The electric utility shall receive all
3585	3585	14 renewable energy credits generated by the project
3586	3586	15 during the first 20 years of operation and retire all
3587	3587	16 renewable energy credits paid for under this item (iv)
3588	3588	17 and return at the end of the delivery term all
3589	3589	18 renewable energy credits that were not paid for.
3590	3590	19 Renewable energy credits generated by the project
3591	3591	20 thereafter shall not be transferred under the
3592	3592	21 renewable energy credit delivery contract with the
3593	3593	22 counterparty electric utility. Notwithstanding the
3594	3594	23 preceding, for those projects participating under item
3595	3595	24 (iii) of subparagraph (K), the contract price for a
3596	3596	25 delivery year shall be based on subscription levels as
3597	3597	26 measured on the higher of the first business day of the
3598	3598
3599	3599
3600	3600
3601	3601
3602	3602
3603	3603	HB5514 - 99 - LRB103 39335 CES 69496 b
3604	3604
3605	3605
3606	3606	HB5514- 100 -LRB103 39335 CES 69496 b HB5514 - 100 - LRB103 39335 CES 69496 b
3607	3607	HB5514 - 100 - LRB103 39335 CES 69496 b
3608	3608	1 delivery year or the first business day 6 months after
3609	3609	2 the first business day of the delivery year.
3610	3610	3 Subscription of 90% of nameplate capacity or greater
3611	3611	4 shall be deemed to be fully subscribed for the
3612	3612	5 purposes of this item (iv). For projects receiving a
3613	3613	6 20-year delivery contract, REC prices shall be
3614	3614	7 adjusted downward for consistency with the incentive
3615	3615	8 levels previously determined to be necessary to
3616	3616	9 support projects under 15-year delivery contracts,
3617	3617	10 taking into consideration any additional new
3618	3618	11 requirements placed on the projects, including, but
3619	3619	12 not limited to, labor standards.
3620	3620	13 (v) Each contract shall include provisions to
3621	3621	14 ensure the delivery of the estimated quantity of
3622	3622	15 renewable energy credits and ongoing collateral
3623	3623	16 requirements and other provisions deemed appropriate
3624	3624	17 by the Agency.
3625	3625	18 (vi) The utility shall be the counterparty to the
3626	3626	19 contracts executed under this subparagraph (L) that
3627	3627	20 are approved by the Commission under the process
3628	3628	21 described in Section 16-111.5 of the Public Utilities
3629	3629	22 Act. No contract shall be executed for an amount that
3630	3630	23 is less than one renewable energy credit per year.
3631	3631	24 (vii) If, at any time, approved applications for
3632	3632	25 the Adjustable Block program exceed funds collected by
3633	3633	26 the electric utility or would cause the Agency to
3634	3634
3635	3635
3636	3636
3637	3637
3638	3638
3639	3639	HB5514 - 100 - LRB103 39335 CES 69496 b
3640	3640
3641	3641
3642	3642	HB5514- 101 -LRB103 39335 CES 69496 b HB5514 - 101 - LRB103 39335 CES 69496 b
3643	3643	HB5514 - 101 - LRB103 39335 CES 69496 b
3644	3644	1 exceed the limitation described in subparagraph (E) of
3645	3645	2 this paragraph (1) on the amount of renewable energy
3646	3646	3 resources that may be procured, then the Agency may
3647	3647	4 consider future uncommitted funds to be reserved for
3648	3648	5 these contracts on a first-come, first-served basis.
3649	3649	6 (viii) Nothing in this Section shall require the
3650	3650	7 utility to advance any payment or pay any amounts that
3651	3651	8 exceed the actual amount of revenues anticipated to be
3652	3652	9 collected by the utility under paragraph (6) of this
3653	3653	10 subsection (c) and subsection (k) of Section 16-108 of
3654	3654	11 the Public Utilities Act inclusive of eligible funds
3655	3655	12 collected in prior years and alternative compliance
3656	3656	13 payments for use by the utility, and contracts
3657	3657	14 executed under this Section shall expressly
3658	3658	15 incorporate this limitation.
3659	3659	16 (ix) Notwithstanding other requirements of this
3660	3660	17 subparagraph (L), no modification shall be required to
3661	3661	18 Adjustable Block program contracts if they were
3662	3662	19 already executed prior to the establishment, approval,
3663	3663	20 and implementation of new contract forms as a result
3664	3664	21 of this amendatory Act of the 102nd General Assembly.
3665	3665	22 (x) Contracts may be assignable, but only to
3666	3666	23 entities first deemed by the Agency to have met
3667	3667	24 program terms and requirements applicable to direct
3668	3668	25 program participation. In developing contracts for the
3669	3669	26 delivery of renewable energy credits, the Agency shall
3670	3670
3671	3671
3672	3672
3673	3673
3674	3674
3675	3675	HB5514 - 101 - LRB103 39335 CES 69496 b
3676	3676
3677	3677
3678	3678	HB5514- 102 -LRB103 39335 CES 69496 b HB5514 - 102 - LRB103 39335 CES 69496 b
3679	3679	HB5514 - 102 - LRB103 39335 CES 69496 b
3680	3680	1 be permitted to establish fees applicable to each
3681	3681	2 contract assignment.
3682	3682	3 (M) The Agency shall be authorized to retain one or
3683	3683	4 more experts or expert consulting firms to develop,
3684	3684	5 administer, implement, operate, and evaluate the
3685	3685	6 Adjustable Block program described in subparagraph (K) of
3686	3686	7 this paragraph (1), and the Agency shall retain the
3687	3687	8 consultant or consultants in the same manner, to the
3688	3688	9 extent practicable, as the Agency retains others to
3689	3689	10 administer provisions of this Act, including, but not
3690	3690	11 limited to, the procurement administrator. The selection
3691	3691	12 of experts and expert consulting firms and the procurement
3692	3692	13 process described in this subparagraph (M) are exempt from
3693	3693	14 the requirements of Section 20-10 of the Illinois
3694	3694	15 Procurement Code, under Section 20-10 of that Code. The
3695	3695	16 Agency shall strive to minimize administrative expenses in
3696	3696	17 the implementation of the Adjustable Block program.
3697	3697	18 The Program Administrator may charge application fees
3698	3698	19 to participating firms to cover the cost of program
3699	3699	20 administration. Any application fee amounts shall
3700	3700	21 initially be determined through the long-term renewable
3701	3701	22 resources procurement plan, and modifications to any
3702	3702	23 application fee that deviate more than 25% from the
3703	3703	24 Commission's approved value must be approved by the
3704	3704	25 Commission as a long-term plan revision under Section
3705	3705	26 16-111.5 of the Public Utilities Act. The Agency shall
3706	3706
3707	3707
3708	3708
3709	3709
3710	3710
3711	3711	HB5514 - 102 - LRB103 39335 CES 69496 b
3712	3712
3713	3713
3714	3714	HB5514- 103 -LRB103 39335 CES 69496 b HB5514 - 103 - LRB103 39335 CES 69496 b
3715	3715	HB5514 - 103 - LRB103 39335 CES 69496 b
3716	3716	1 consider stakeholder feedback when making adjustments to
3717	3717	2 application fees and shall notify stakeholders in advance
3718	3718	3 of any planned changes.
3719	3719	4 In addition to covering the costs of program
3720	3720	5 administration, the Agency, in conjunction with its
3721	3721	6 Program Administrator, may also use the proceeds of such
3722	3722	7 fees charged to participating firms to support public
3723	3723	8 education and ongoing regional and national coordination
3724	3724	9 with nonprofit organizations, public bodies, and others
3725	3725	10 engaged in the implementation of renewable energy
3726	3726	11 incentive programs or similar initiatives. This work may
3727	3727	12 include developing papers and reports, hosting regional
3728	3728	13 and national conferences, and other work deemed necessary
3729	3729	14 by the Agency to position the State of Illinois as a
3730	3730	15 national leader in renewable energy incentive program
3731	3731	16 development and administration.
3732	3732	17 The Agency and its consultant or consultants shall
3733	3733	18 monitor block activity, share program activity with
3734	3734	19 stakeholders and conduct quarterly meetings to discuss
3735	3735	20 program activity and market conditions. If necessary, the
3736	3736	21 Agency may make prospective administrative adjustments to
3737	3737	22 the Adjustable Block program design, such as making
3738	3738	23 adjustments to purchase prices as necessary to achieve the
3739	3739	24 goals of this subsection (c). Program modifications to any
3740	3740	25 block price that do not deviate from the Commission's
3741	3741	26 approved value by more than 10% shall take effect
3742	3742
3743	3743
3744	3744
3745	3745
3746	3746
3747	3747	HB5514 - 103 - LRB103 39335 CES 69496 b
3748	3748
3749	3749
3750	3750	HB5514- 104 -LRB103 39335 CES 69496 b HB5514 - 104 - LRB103 39335 CES 69496 b
3751	3751	HB5514 - 104 - LRB103 39335 CES 69496 b
3752	3752	1 immediately and are not subject to Commission review and
3753	3753	2 approval. Program modifications to any block price that
3754	3754	3 deviate more than 10% from the Commission's approved value
3755	3755	4 must be approved by the Commission as a long-term plan
3756	3756	5 amendment under Section 16-111.5 of the Public Utilities
3757	3757	6 Act. The Agency shall consider stakeholder feedback when
3758	3758	7 making adjustments to the Adjustable Block design and
3759	3759	8 shall notify stakeholders in advance of any planned
3760	3760	9 changes.
3761	3761	10 The Agency and its program administrators for both the
3762	3762	11 Adjustable Block program and the Illinois Solar for All
3763	3763	12 Program, consistent with the requirements of this
3764	3764	13 subsection (c) and subsection (b) of Section 1-56 of this
3765	3765	14 Act, shall propose the Adjustable Block program terms,
3766	3766	15 conditions, and requirements, including the prices to be
3767	3767	16 paid for renewable energy credits, where applicable, and
3768	3768	17 requirements applicable to participating entities and
3769	3769	18 project applications, through the development, review, and
3770	3770	19 approval of the Agency's long-term renewable resources
3771	3771	20 procurement plan described in this subsection (c) and
3772	3772	21 paragraph (5) of subsection (b) of Section 16-111.5 of the
3773	3773	22 Public Utilities Act. Terms, conditions, and requirements
3774	3774	23 for program participation shall include the following:
3775	3775	24 (i) The Agency shall establish a registration
3776	3776	25 process for entities seeking to qualify for
3777	3777	26 program-administered incentive funding and establish
3778	3778
3779	3779
3780	3780
3781	3781
3782	3782
3783	3783	HB5514 - 104 - LRB103 39335 CES 69496 b
3784	3784
3785	3785
3786	3786	HB5514- 105 -LRB103 39335 CES 69496 b HB5514 - 105 - LRB103 39335 CES 69496 b
3787	3787	HB5514 - 105 - LRB103 39335 CES 69496 b
3788	3788	1 baseline qualifications for vendor approval. The
3789	3789	2 Agency must maintain a list of approved entities on
3790	3790	3 each program's website, and may revoke a vendor's
3791	3791	4 ability to receive program-administered incentive
3792	3792	5 funding status upon a determination that the vendor
3793	3793	6 failed to comply with contract terms, the law, or
3794	3794	7 other program requirements.
3795	3795	8 (ii) The Agency shall establish program
3796	3796	9 requirements and minimum contract terms to ensure
3797	3797	10 projects are properly installed and produce their
3798	3798	11 expected amounts of energy. Program requirements may
3799	3799	12 include on-site inspections and photo documentation of
3800	3800	13 projects under construction. The Agency may require
3801	3801	14 repairs, alterations, or additions to remedy any
3802	3802	15 material deficiencies discovered. Vendors who have a
3803	3803	16 disproportionately high number of deficient systems
3804	3804	17 may lose their eligibility to continue to receive
3805	3805	18 State-administered incentive funding through Agency
3806	3806	19 programs and procurements.
3807	3807	20 (iii) To discourage deceptive marketing or other
3808	3808	21 bad faith business practices, the Agency may require
3809	3809	22 direct program participants, including agents
3810	3810	23 operating on their behalf, to provide standardized
3811	3811	24 disclosures to a customer prior to that customer's
3812	3812	25 execution of a contract for the development of a
3813	3813	26 distributed generation system or a subscription to a
3814	3814
3815	3815
3816	3816
3817	3817
3818	3818
3819	3819	HB5514 - 105 - LRB103 39335 CES 69496 b
3820	3820
3821	3821
3822	3822	HB5514- 106 -LRB103 39335 CES 69496 b HB5514 - 106 - LRB103 39335 CES 69496 b
3823	3823	HB5514 - 106 - LRB103 39335 CES 69496 b
3824	3824	1 community solar project.
3825	3825	2 (iv) The Agency shall establish one or multiple
3826	3826	3 Consumer Complaints Centers to accept complaints
3827	3827	4 regarding businesses that participate in, or otherwise
3828	3828	5 benefit from, State-administered incentive funding
3829	3829	6 through Agency-administered programs. The Agency shall
3830	3830	7 maintain a public database of complaints with any
3831	3831	8 confidential or particularly sensitive information
3832	3832	9 redacted from public entries.
3833	3833	10 (v) Through a filing in the proceeding for the
3834	3834	11 approval of its long-term renewable energy resources
3835	3835	12 procurement plan, the Agency shall provide an annual
3836	3836	13 written report to the Illinois Commerce Commission
3837	3837	14 documenting the frequency and nature of complaints and
3838	3838	15 any enforcement actions taken in response to those
3839	3839	16 complaints.
3840	3840	17 (vi) The Agency shall schedule regular meetings
3841	3841	18 with representatives of the Office of the Attorney
3842	3842	19 General, the Illinois Commerce Commission, consumer
3843	3843	20 protection groups, and other interested stakeholders
3844	3844	21 to share relevant information about consumer
3845	3845	22 protection, project compliance, and complaints
3846	3846	23 received.
3847	3847	24 (vii) To the extent that complaints received
3848	3848	25 implicate the jurisdiction of the Office of the
3849	3849	26 Attorney General, the Illinois Commerce Commission, or
3850	3850
3851	3851
3852	3852
3853	3853
3854	3854
3855	3855	HB5514 - 106 - LRB103 39335 CES 69496 b
3856	3856
3857	3857
3858	3858	HB5514- 107 -LRB103 39335 CES 69496 b HB5514 - 107 - LRB103 39335 CES 69496 b
3859	3859	HB5514 - 107 - LRB103 39335 CES 69496 b
3860	3860	1 local, State, or federal law enforcement, the Agency
3861	3861	2 shall also refer complaints to those entities as
3862	3862	3 appropriate.
3863	3863	4 (N) The Agency shall establish the terms, conditions,
3864	3864	5 and program requirements for photovoltaic community
3865	3865	6 renewable generation projects with a goal to expand access
3866	3866	7 to a broader group of energy consumers, to ensure robust
3867	3867	8 participation opportunities for residential and small
3868	3868	9 commercial customers and those who cannot install
3869	3869	10 renewable energy on their own properties. Subject to
3870	3870	11 reasonable limitations, any plan approved by the
3871	3871	12 Commission shall allow subscriptions to community
3872	3872	13 renewable generation projects to be portable and
3873	3873	14 transferable. For purposes of this subparagraph (N),
3874	3874	15 "portable" means that subscriptions may be retained by the
3875	3875	16 subscriber even if the subscriber relocates or changes its
3876	3876	17 address within the same utility service territory; and
3877	3877	18 "transferable" means that a subscriber may assign or sell
3878	3878	19 subscriptions to another person within the same utility
3879	3879	20 service territory.
3880	3880	21 Through the development of its long-term renewable
3881	3881	22 resources procurement plan, the Agency may consider
3882	3882	23 whether community renewable generation projects utilizing
3883	3883	24 technologies other than photovoltaics should be supported
3884	3884	25 through State-administered incentive funding, and may
3885	3885	26 issue requests for information to gauge market demand.
3886	3886
3887	3887
3888	3888
3889	3889
3890	3890
3891	3891	HB5514 - 107 - LRB103 39335 CES 69496 b
3892	3892
3893	3893
3894	3894	HB5514- 108 -LRB103 39335 CES 69496 b HB5514 - 108 - LRB103 39335 CES 69496 b
3895	3895	HB5514 - 108 - LRB103 39335 CES 69496 b
3896	3896	1 Electric utilities shall provide a monetary credit to
3897	3897	2 a subscriber's subsequent bill for service for the
3898	3898	3 proportional output of a community renewable generation
3899	3899	4 project attributable to that subscriber as specified in
3900	3900	5 Section 16-107.5 of the Public Utilities Act.
3901	3901	6 The Agency shall purchase renewable energy credits
3902	3902	7 from subscribed shares of photovoltaic community renewable
3903	3903	8 generation projects through the Adjustable Block program
3904	3904	9 described in subparagraph (K) of this paragraph (1) or
3905	3905	10 through the Illinois Solar for All Program described in
3906	3906	11 Section 1-56 of this Act. The electric utility shall
3907	3907	12 purchase any unsubscribed energy from community renewable
3908	3908	13 generation projects that are Qualifying Facilities ("QF")
3909	3909	14 under the electric utility's tariff for purchasing the
3910	3910	15 output from QFs under Public Utilities Regulatory Policies
3911	3911	16 Act of 1978.
3912	3912	17 The owners of and any subscribers to a community
3913	3913	18 renewable generation project shall not be considered
3914	3914	19 public utilities or alternative retail electricity
3915	3915	20 suppliers under the Public Utilities Act solely as a
3916	3916	21 result of their interest in or subscription to a community
3917	3917	22 renewable generation project and shall not be required to
3918	3918	23 become an alternative retail electric supplier by
3919	3919	24 participating in a community renewable generation project
3920	3920	25 with a public utility.
3921	3921	26 (O) For the delivery year beginning June 1, 2018, the
3922	3922
3923	3923
3924	3924
3925	3925
3926	3926
3927	3927	HB5514 - 108 - LRB103 39335 CES 69496 b
3928	3928
3929	3929
3930	3930	HB5514- 109 -LRB103 39335 CES 69496 b HB5514 - 109 - LRB103 39335 CES 69496 b
3931	3931	HB5514 - 109 - LRB103 39335 CES 69496 b
3932	3932	1 long-term renewable resources procurement plan required by
3933	3933	2 this subsection (c) shall provide for the Agency to
3934	3934	3 procure contracts to continue offering the Illinois Solar
3935	3935	4 for All Program described in subsection (b) of Section
3936	3936	5 1-56 of this Act, and the contracts approved by the
3937	3937	6 Commission shall be executed by the utilities that are
3938	3938	7 subject to this subsection (c). The long-term renewable
3939	3939	8 resources procurement plan shall allocate up to
3940	3940	9 $50,000,000 per delivery year to fund the programs, and
3941	3941	10 the plan shall determine the amount of funding to be
3942	3942	11 apportioned to the programs identified in subsection (b)
3943	3943	12 of Section 1-56 of this Act; provided that for the
3944	3944	13 delivery years beginning June 1, 2021, June 1, 2022, and
3945	3945	14 June 1, 2023, the long-term renewable resources
3946	3946	15 procurement plan may average the annual budgets over a
3947	3947	16 3-year period to account for program ramp-up. For the
3948	3948	17 delivery years beginning June 1, 2021, June 1, 2024, June
3949	3949	18 1, 2027, and June 1, 2030 and additional $10,000,000 shall
3950	3950	19 be provided to the Department of Commerce and Economic
3951	3951	20 Opportunity to implement the workforce development
3952	3952	21 programs and reporting as outlined in Section 16-108.12 of
3953	3953	22 the Public Utilities Act. In making the determinations
3954	3954	23 required under this subparagraph (O), the Commission shall
3955	3955	24 consider the experience and performance under the programs
3956	3956	25 and any evaluation reports. The Commission shall also
3957	3957	26 provide for an independent evaluation of those programs on
3958	3958
3959	3959
3960	3960
3961	3961
3962	3962
3963	3963	HB5514 - 109 - LRB103 39335 CES 69496 b
3964	3964
3965	3965
3966	3966	HB5514- 110 -LRB103 39335 CES 69496 b HB5514 - 110 - LRB103 39335 CES 69496 b
3967	3967	HB5514 - 110 - LRB103 39335 CES 69496 b
3968	3968	1 a periodic basis that are funded under this subparagraph
3969	3969	2 (O).
3970	3970	3 (P) All programs and procurements under this
3971	3971	4 subsection (c) shall be designed to encourage
3972	3972	5 participating projects to use a diverse and equitable
3973	3973	6 workforce and a diverse set of contractors, including
3974	3974	7 minority-owned businesses, disadvantaged businesses,
3975	3975	8 trade unions, graduates of any workforce training programs
3976	3976	9 administered under this Act, and small businesses.
3977	3977	10 The Agency shall develop a method to optimize
3978	3978	11 procurement of renewable energy credits from proposed
3979	3979	12 utility-scale projects that are located in communities
3980	3980	13 eligible to receive Energy Transition Community Grants
3981	3981	14 pursuant to Section 10-20 of the Energy Community
3982	3982	15 Reinvestment Act. If this requirement conflicts with other
3983	3983	16 provisions of law or the Agency determines that full
3984	3984	17 compliance with the requirements of this subparagraph (P)
3985	3985	18 would be unreasonably costly or administratively
3986	3986	19 impractical, the Agency is to propose alternative
3987	3987	20 approaches to achieve development of renewable energy
3988	3988	21 resources in communities eligible to receive Energy
3989	3989	22 Transition Community Grants pursuant to Section 10-20 of
3990	3990	23 the Energy Community Reinvestment Act or seek an exemption
3991	3991	24 from this requirement from the Commission.
3992	3992	25 (Q) Each facility listed in subitems (i) through (ix)
3993	3993	26 of item (1) of this subparagraph (Q) for which a renewable
3994	3994
3995	3995
3996	3996
3997	3997
3998	3998
3999	3999	HB5514 - 110 - LRB103 39335 CES 69496 b
4000	4000
4001	4001
4002	4002	HB5514- 111 -LRB103 39335 CES 69496 b HB5514 - 111 - LRB103 39335 CES 69496 b
4003	4003	HB5514 - 111 - LRB103 39335 CES 69496 b
4004	4004	1 energy credit delivery contract is signed after the
4005	4005	2 effective date of this amendatory Act of the 102nd General
4006	4006	3 Assembly is subject to the following requirements through
4007	4007	4 the Agency's long-term renewable resources procurement
4008	4008	5 plan:
4009	4009	6 (1) Each facility shall be subject to the
4010	4010	7 prevailing wage requirements included in the
4011	4011	8 Prevailing Wage Act. The Agency shall require
4012	4012	9 verification that all construction performed on the
4013	4013	10 facility by the renewable energy credit delivery
4014	4014	11 contract holder, its contractors, or its
4015	4015	12 subcontractors relating to construction of the
4016	4016	13 facility is performed by construction employees
4017	4017	14 receiving an amount for that work equal to or greater
4018	4018	15 than the general prevailing rate, as that term is
4019	4019	16 defined in Section 3 of the Prevailing Wage Act. For
4020	4020	17 purposes of this item (1), "house of worship" means
4021	4021	18 property that is both (1) used exclusively by a
4022	4022	19 religious society or body of persons as a place for
4023	4023	20 religious exercise or religious worship and (2)
4024	4024	21 recognized as exempt from taxation pursuant to Section
4025	4025	22 15-40 of the Property Tax Code. This item (1) shall
4026	4026	23 apply to any the following:
4027	4027	24 (i) all new utility-scale wind projects;
4028	4028	25 (ii) all new utility-scale photovoltaic
4029	4029	26 projects;
4030	4030
4031	4031
4032	4032
4033	4033
4034	4034
4035	4035	HB5514 - 111 - LRB103 39335 CES 69496 b
4036	4036
4037	4037
4038	4038	HB5514- 112 -LRB103 39335 CES 69496 b HB5514 - 112 - LRB103 39335 CES 69496 b
4039	4039	HB5514 - 112 - LRB103 39335 CES 69496 b
4040	4040	1 (iii) all new brownfield photovoltaic
4041	4041	2 projects;
4042	4042	3 (iv) all new photovoltaic community renewable
4043	4043	4 energy facilities that qualify for item (iii) of
4044	4044	5 subparagraph (K) of this paragraph (1);
4045	4045	6 (v) all new community driven community
4046	4046	7 photovoltaic projects that qualify for item (v) of
4047	4047	8 subparagraph (K) of this paragraph (1);
4048	4048	9 (vi) all new photovoltaic projects on public
4049	4049	10 school land that qualify for item (iv) of
4050	4050	11 subparagraph (K) of this paragraph (1);
4051	4051	12 (vii) all new photovoltaic distributed
4052	4052	13 renewable energy generation devices that (1)
4053	4053	14 qualify for item (i) of subparagraph (K) of this
4054	4054	15 paragraph (1); (2) are not projects that serve
4055	4055	16 single-family or multi-family residential
4056	4056	17 buildings; and (3) are not houses of worship where
4057	4057	18 the aggregate capacity including collocated
4058	4058	19 projects would not exceed 100 kilowatts;
4059	4059	20 (viii) all new photovoltaic distributed
4060	4060	21 renewable energy generation devices that (1)
4061	4061	22 qualify for item (ii) of subparagraph (K) of this
4062	4062	23 paragraph (1); (2) are not projects that serve
4063	4063	24 single-family or multi-family residential
4064	4064	25 buildings; and (3) are not houses of worship where
4065	4065	26 the aggregate capacity including collocated
4066	4066
4067	4067
4068	4068
4069	4069
4070	4070
4071	4071	HB5514 - 112 - LRB103 39335 CES 69496 b
4072	4072
4073	4073
4074	4074	HB5514- 113 -LRB103 39335 CES 69496 b HB5514 - 113 - LRB103 39335 CES 69496 b
4075	4075	HB5514 - 113 - LRB103 39335 CES 69496 b
4076	4076	1 projects would not exceed 100 kilowatts;
4077	4077	2 (ix) all new, modernized, or retooled
4078	4078	3 hydropower facilities.
4079	4079	4 (2) Renewable energy credits procured from new
4080	4080	5 utility-scale wind projects, new utility-scale solar
4081	4081	6 projects, and new brownfield solar projects pursuant
4082	4082	7 to Agency procurement events occurring after the
4083	4083	8 effective date of this amendatory Act of the 102nd
4084	4084	9 General Assembly must be from facilities built by
4085	4085	10 general contractors that must enter into a project
4086	4086	11 labor agreement, as defined by this Act, prior to
4087	4087	12 construction. The project labor agreement shall be
4088	4088	13 filed with the Director in accordance with procedures
4089	4089	14 established by the Agency through its long-term
4090	4090	15 renewable resources procurement plan. Any information
4091	4091	16 submitted to the Agency in this item (2) shall be
4092	4092	17 considered commercially sensitive information. At a
4093	4093	18 minimum, the project labor agreement must provide the
4094	4094	19 names, addresses, and occupations of the owner of the
4095	4095	20 plant and the individuals representing the labor
4096	4096	21 organization employees participating in the project
4097	4097	22 labor agreement consistent with the Project Labor
4098	4098	23 Agreements Act. The agreement must also specify the
4099	4099	24 terms and conditions as defined by this Act.
4100	4100	25 (3) It is the intent of this Section to ensure that
4101	4101	26 economic development occurs across Illinois
4102	4102
4103	4103
4104	4104
4105	4105
4106	4106
4107	4107	HB5514 - 113 - LRB103 39335 CES 69496 b
4108	4108
4109	4109
4110	4110	HB5514- 114 -LRB103 39335 CES 69496 b HB5514 - 114 - LRB103 39335 CES 69496 b
4111	4111	HB5514 - 114 - LRB103 39335 CES 69496 b
4112	4112	1 communities, that emerging businesses may grow, and
4113	4113	2 that there is improved access to the clean energy
4114	4114	3 economy by persons who have greater economic burdens
4115	4115	4 to success. The Agency shall take into consideration
4116	4116	5 the unique cost of compliance of this subparagraph (Q)
4117	4117	6 that might be borne by equity eligible contractors,
4118	4118	7 shall include such costs when determining the price of
4119	4119	8 renewable energy credits in the Adjustable Block
4120	4120	9 program, and shall take such costs into consideration
4121	4121	10 in a nondiscriminatory manner when comparing bids for
4122	4122	11 competitive procurements. The Agency shall consider
4123	4123	12 costs associated with compliance whether in the
4124	4124	13 development, financing, or construction of projects.
4125	4125	14 The Agency shall periodically review the assumptions
4126	4126	15 in these costs and may adjust prices, in compliance
4127	4127	16 with subparagraph (M) of this paragraph (1).
4128	4128	17 (R) In its long-term renewable resources procurement
4129	4129	18 plan, the Agency shall establish a self-direct renewable
4130	4130	19 portfolio standard compliance program for eligible
4131	4131	20 self-direct customers that purchase renewable energy
4132	4132	21 credits from utility-scale wind and solar projects through
4133	4133	22 long-term agreements for purchase of renewable energy
4134	4134	23 credits as described in this Section. Such long-term
4135	4135	24 agreements may include the purchase of energy or other
4136	4136	25 products on a physical or financial basis and may involve
4137	4137	26 an alternative retail electric supplier as defined in
4138	4138
4139	4139
4140	4140
4141	4141
4142	4142
4143	4143	HB5514 - 114 - LRB103 39335 CES 69496 b
4144	4144
4145	4145
4146	4146	HB5514- 115 -LRB103 39335 CES 69496 b HB5514 - 115 - LRB103 39335 CES 69496 b
4147	4147	HB5514 - 115 - LRB103 39335 CES 69496 b
4148	4148	1 Section 16-102 of the Public Utilities Act. This program
4149	4149	2 shall take effect in the delivery year commencing June 1,
4150	4150	3 2023.
4151	4151	4 (1) For the purposes of this subparagraph:
4152	4152	5 "Eligible self-direct customer" means any retail
4153	4153	6 customers of an electric utility that serves 3,000,000
4154	4154	7 or more retail customers in the State and whose total
4155	4155	8 highest 30-minute demand was more than 10,000
4156	4156	9 kilowatts, or any retail customers of an electric
4157	4157	10 utility that serves less than 3,000,000 retail
4158	4158	11 customers but more than 500,000 retail customers in
4159	4159	12 the State and whose total highest 15-minute demand was
4160	4160	13 more than 10,000 kilowatts.
4161	4161	14 "Retail customer" has the meaning set forth in
4162	4162	15 Section 16-102 of the Public Utilities Act and
4163	4163	16 multiple retail customer accounts under the same
4164	4164	17 corporate parent may aggregate their account demands
4165	4165	18 to meet the 10,000 kilowatt threshold. The criteria
4166	4166	19 for determining whether this subparagraph is
4167	4167	20 applicable to a retail customer shall be based on the
4168	4168	21 12 consecutive billing periods prior to the start of
4169	4169	22 the year in which the application is filed.
4170	4170	23 (2) For renewable energy credits to count toward
4171	4171	24 the self-direct renewable portfolio standard
4172	4172	25 compliance program, they must:
4173	4173	26 (i) qualify as renewable energy credits as
4174	4174
4175	4175
4176	4176
4177	4177
4178	4178
4179	4179	HB5514 - 115 - LRB103 39335 CES 69496 b
4180	4180
4181	4181
4182	4182	HB5514- 116 -LRB103 39335 CES 69496 b HB5514 - 116 - LRB103 39335 CES 69496 b
4183	4183	HB5514 - 116 - LRB103 39335 CES 69496 b
4184	4184	1 defined in Section 1-10 of this Act;
4185	4185	2 (ii) be sourced from one or more renewable
4186	4186	3 energy generating facilities that comply with the
4187	4187	4 geographic requirements as set forth in
4188	4188	5 subparagraph (I) of paragraph (1) of subsection
4189	4189	6 (c) as interpreted through the Agency's long-term
4190	4190	7 renewable resources procurement plan, or, where
4191	4191	8 applicable, the geographic requirements that
4192	4192	9 governed utility-scale renewable energy credits at
4193	4193	10 the time the eligible self-direct customer entered
4194	4194	11 into the applicable renewable energy credit
4195	4195	12 purchase agreement;
4196	4196	13 (iii) be procured through long-term contracts
4197	4197	14 with term lengths of at least 10 years either
4198	4198	15 directly with the renewable energy generating
4199	4199	16 facility or through a bundled power purchase
4200	4200	17 agreement, a virtual power purchase agreement, an
4201	4201	18 agreement between the renewable generating
4202	4202	19 facility, an alternative retail electric supplier,
4203	4203	20 and the customer, or such other structure as is
4204	4204	21 permissible under this subparagraph (R);
4205	4205	22 (iv) be equivalent in volume to at least 40%
4206	4206	23 of the eligible self-direct customer's usage,
4207	4207	24 determined annually by the eligible self-direct
4208	4208	25 customer's usage during the previous delivery
4209	4209	26 year, measured to the nearest megawatt-hour;
4210	4210
4211	4211
4212	4212
4213	4213
4214	4214
4215	4215	HB5514 - 116 - LRB103 39335 CES 69496 b
4216	4216
4217	4217
4218	4218	HB5514- 117 -LRB103 39335 CES 69496 b HB5514 - 117 - LRB103 39335 CES 69496 b
4219	4219	HB5514 - 117 - LRB103 39335 CES 69496 b
4220	4220	1 (v) be retired by or on behalf of the large
4221	4221	2 energy customer;
4222	4222	3 (vi) be sourced from new utility-scale wind
4223	4223	4 projects or new utility-scale solar projects; and
4224	4224	5 (vii) if the contracts for renewable energy
4225	4225	6 credits are entered into after the effective date
4226	4226	7 of this amendatory Act of the 102nd General
4227	4227	8 Assembly, the new utility-scale wind projects or
4228	4228	9 new utility-scale solar projects must comply with
4229	4229	10 the requirements established in subparagraphs (P)
4230	4230	11 and (Q) of paragraph (1) of this subsection (c)
4231	4231	12 and subsection (c-10).
4232	4232	13 (3) The self-direct renewable portfolio standard
4233	4233	14 compliance program shall be designed to allow eligible
4234	4234	15 self-direct customers to procure new renewable energy
4235	4235	16 credits from new utility-scale wind projects or new
4236	4236	17 utility-scale photovoltaic projects. The Agency shall
4237	4237	18 annually determine the amount of utility-scale
4238	4238	19 renewable energy credits it will include each year
4239	4239	20 from the self-direct renewable portfolio standard
4240	4240	21 compliance program, subject to receiving qualifying
4241	4241	22 applications. In making this determination, the Agency
4242	4242	23 shall evaluate publicly available analyses and studies
4243	4243	24 of the potential market size for utility-scale
4244	4244	25 renewable energy long-term purchase agreements by
4245	4245	26 commercial and industrial energy customers and make
4246	4246
4247	4247
4248	4248
4249	4249
4250	4250
4251	4251	HB5514 - 117 - LRB103 39335 CES 69496 b
4252	4252
4253	4253
4254	4254	HB5514- 118 -LRB103 39335 CES 69496 b HB5514 - 118 - LRB103 39335 CES 69496 b
4255	4255	HB5514 - 118 - LRB103 39335 CES 69496 b
4256	4256	1 that report publicly available. If demand for
4257	4257	2 participation in the self-direct renewable portfolio
4258	4258	3 standard compliance program exceeds availability, the
4259	4259	4 Agency shall ensure participation is evenly split
4260	4260	5 between commercial and industrial users to the extent
4261	4261	6 there is sufficient demand from both customer classes.
4262	4262	7 Each renewable energy credit procured pursuant to this
4263	4263	8 subparagraph (R) by a self-direct customer shall
4264	4264	9 reduce the total volume of renewable energy credits
4265	4265	10 the Agency is otherwise required to procure from new
4266	4266	11 utility-scale projects pursuant to subparagraph (C) of
4267	4267	12 paragraph (1) of this subsection (c) on behalf of
4268	4268	13 contracting utilities where the eligible self-direct
4269	4269	14 customer is located. The self-direct customer shall
4270	4270	15 file an annual compliance report with the Agency
4271	4271	16 pursuant to terms established by the Agency through
4272	4272	17 its long-term renewable resources procurement plan to
4273	4273	18 be eligible for participation in this program.
4274	4274	19 Customers must provide the Agency with their most
4275	4275	20 recent electricity billing statements or other
4276	4276	21 information deemed necessary by the Agency to
4277	4277	22 demonstrate they are an eligible self-direct customer.
4278	4278	23 (4) The Commission shall approve a reduction in
4279	4279	24 the volumetric charges collected pursuant to Section
4280	4280	25 16-108 of the Public Utilities Act for approved
4281	4281	26 eligible self-direct customers equivalent to the
4282	4282
4283	4283
4284	4284
4285	4285
4286	4286
4287	4287	HB5514 - 118 - LRB103 39335 CES 69496 b
4288	4288
4289	4289
4290	4290	HB5514- 119 -LRB103 39335 CES 69496 b HB5514 - 119 - LRB103 39335 CES 69496 b
4291	4291	HB5514 - 119 - LRB103 39335 CES 69496 b
4292	4292	1 anticipated cost of renewable energy credit deliveries
4293	4293	2 under contracts for new utility-scale wind and new
4294	4294	3 utility-scale solar entered for each delivery year
4295	4295	4 after the large energy customer begins retiring
4296	4296	5 eligible new utility scale renewable energy credits
4297	4297	6 for self-compliance. The self-direct credit amount
4298	4298	7 shall be determined annually and is equal to the
4299	4299	8 estimated portion of the cost authorized by
4300	4300	9 subparagraph (E) of paragraph (1) of this subsection
4301	4301	10 (c) that supported the annual procurement of
4302	4302	11 utility-scale renewable energy credits in the prior
4303	4303	12 delivery year using a methodology described in the
4304	4304	13 long-term renewable resources procurement plan,
4305	4305	14 expressed on a per kilowatthour basis, and does not
4306	4306	15 include (i) costs associated with any contracts
4307	4307	16 entered into before the delivery year in which the
4308	4308	17 customer files the initial compliance report to be
4309	4309	18 eligible for participation in the self-direct program,
4310	4310	19 and (ii) costs associated with procuring renewable
4311	4311	20 energy credits through existing and future contracts
4312	4312	21 through the Adjustable Block Program, subsection (c-5)
4313	4313	22 of this Section 1-75, and the Solar for All Program.
4314	4314	23 The Agency shall assist the Commission in determining
4315	4315	24 the current and future costs. The Agency must
4316	4316	25 determine the self-direct credit amount for new and
4317	4317	26 existing eligible self-direct customers and submit
4318	4318
4319	4319
4320	4320
4321	4321
4322	4322
4323	4323	HB5514 - 119 - LRB103 39335 CES 69496 b
4324	4324
4325	4325
4326	4326	HB5514- 120 -LRB103 39335 CES 69496 b HB5514 - 120 - LRB103 39335 CES 69496 b
4327	4327	HB5514 - 120 - LRB103 39335 CES 69496 b
4328	4328	1 this to the Commission in an annual compliance filing.
4329	4329	2 The Commission must approve the self-direct credit
4330	4330	3 amount by June 1, 2023 and June 1 of each delivery year
4331	4331	4 thereafter.
4332	4332	5 (5) Customers described in this subparagraph (R)
4333	4333	6 shall apply, on a form developed by the Agency, to the
4334	4334	7 Agency to be designated as a self-direct eligible
4335	4335	8 customer. Once the Agency determines that a
4336	4336	9 self-direct customer is eligible for participation in
4337	4337	10 the program, the self-direct customer will remain
4338	4338	11 eligible until the end of the term of the contract.
4339	4339	12 Thereafter, application may be made not less than 12
4340	4340	13 months before the filing date of the long-term
4341	4341	14 renewable resources procurement plan described in this
4342	4342	15 Act. At a minimum, such application shall contain the
4343	4343	16 following:
4344	4344	17 (i) the customer's certification that, at the
4345	4345	18 time of the customer's application, the customer
4346	4346	19 qualifies to be a self-direct eligible customer,
4347	4347	20 including documents demonstrating that
4348	4348	21 qualification;
4349	4349	22 (ii) the customer's certification that the
4350	4350	23 customer has entered into or will enter into by
4351	4351	24 the beginning of the applicable procurement year,
4352	4352	25 one or more bilateral contracts for new wind
4353	4353	26 projects or new photovoltaic projects, including
4354	4354
4355	4355
4356	4356
4357	4357
4358	4358
4359	4359	HB5514 - 120 - LRB103 39335 CES 69496 b
4360	4360
4361	4361
4362	4362	HB5514- 121 -LRB103 39335 CES 69496 b HB5514 - 121 - LRB103 39335 CES 69496 b
4363	4363	HB5514 - 121 - LRB103 39335 CES 69496 b
4364	4364	1 supporting documentation;
4365	4365	2 (iii) certification that the contract or
4366	4366	3 contracts for new renewable energy resources are
4367	4367	4 long-term contracts with term lengths of at least
4368	4368	5 10 years, including supporting documentation;
4369	4369	6 (iv) certification of the quantities of
4370	4370	7 renewable energy credits that the customer will
4371	4371	8 purchase each year under such contract or
4372	4372	9 contracts, including supporting documentation;
4373	4373	10 (v) proof that the contract is sufficient to
4374	4374	11 produce renewable energy credits to be equivalent
4375	4375	12 in volume to at least 40% of the large energy
4376	4376	13 customer's usage from the previous delivery year,
4377	4377	14 measured to the nearest megawatt-hour; and
4378	4378	15 (vi) certification that the customer intends
4379	4379	16 to maintain the contract for the duration of the
4380	4380	17 length of the contract.
4381	4381	18 (6) If a customer receives the self-direct credit
4382	4382	19 but fails to properly procure and retire renewable
4383	4383	20 energy credits as required under this subparagraph
4384	4384	21 (R), the Commission, on petition from the Agency and
4385	4385	22 after notice and hearing, may direct such customer's
4386	4386	23 utility to recover the cost of the wrongfully received
4387	4387	24 self-direct credits plus interest through an adder to
4388	4388	25 charges assessed pursuant to Section 16-108 of the
4389	4389	26 Public Utilities Act. Self-direct customers who
4390	4390
4391	4391
4392	4392
4393	4393
4394	4394
4395	4395	HB5514 - 121 - LRB103 39335 CES 69496 b
4396	4396
4397	4397
4398	4398	HB5514- 122 -LRB103 39335 CES 69496 b HB5514 - 122 - LRB103 39335 CES 69496 b
4399	4399	HB5514 - 122 - LRB103 39335 CES 69496 b
4400	4400	1 knowingly fail to properly procure and retire
4401	4401	2 renewable energy credits and do not notify the Agency
4402	4402	3 are ineligible for continued participation in the
4403	4403	4 self-direct renewable portfolio standard compliance
4404	4404	5 program.
4405	4405	6 (2) (Blank).
4406	4406	7 (3) (Blank).
4407	4407	8 (4) The electric utility shall retire all renewable
4408	4408	9 energy credits used to comply with the standard.
4409	4409	10 (5) Beginning with the 2010 delivery year and ending
4410	4410	11 June 1, 2017, an electric utility subject to this
4411	4411	12 subsection (c) shall apply the lesser of the maximum
4412	4412	13 alternative compliance payment rate or the most recent
4413	4413	14 estimated alternative compliance payment rate for its
4414	4414	15 service territory for the corresponding compliance period,
4415	4415	16 established pursuant to subsection (d) of Section 16-115D
4416	4416	17 of the Public Utilities Act to its retail customers that
4417	4417	18 take service pursuant to the electric utility's hourly
4418	4418	19 pricing tariff or tariffs. The electric utility shall
4419	4419	20 retain all amounts collected as a result of the
4420	4420	21 application of the alternative compliance payment rate or
4421	4421	22 rates to such customers, and, beginning in 2011, the
4422	4422	23 utility shall include in the information provided under
4423	4423	24 item (1) of subsection (d) of Section 16-111.5 of the
4424	4424	25 Public Utilities Act the amounts collected under the
4425	4425	26 alternative compliance payment rate or rates for the prior
4426	4426
4427	4427
4428	4428
4429	4429
4430	4430
4431	4431	HB5514 - 122 - LRB103 39335 CES 69496 b
4432	4432
4433	4433
4434	4434	HB5514- 123 -LRB103 39335 CES 69496 b HB5514 - 123 - LRB103 39335 CES 69496 b
4435	4435	HB5514 - 123 - LRB103 39335 CES 69496 b
4436	4436	1 year ending May 31. Notwithstanding any limitation on the
4437	4437	2 procurement of renewable energy resources imposed by item
4438	4438	3 (2) of this subsection (c), the Agency shall increase its
4439	4439	4 spending on the purchase of renewable energy resources to
4440	4440	5 be procured by the electric utility for the next plan year
4441	4441	6 by an amount equal to the amounts collected by the utility
4442	4442	7 under the alternative compliance payment rate or rates in
4443	4443	8 the prior year ending May 31.
4444	4444	9 (6) The electric utility shall be entitled to recover
4445	4445	10 all of its costs associated with the procurement of
4446	4446	11 renewable energy credits under plans approved under this
4447	4447	12 Section and Section 16-111.5 of the Public Utilities Act.
4448	4448	13 These costs shall include associated reasonable expenses
4449	4449	14 for implementing the procurement programs, including, but
4450	4450	15 not limited to, the costs of administering and evaluating
4451	4451	16 the Adjustable Block program, through an automatic
4452	4452	17 adjustment clause tariff in accordance with subsection (k)
4453	4453	18 of Section 16-108 of the Public Utilities Act.
4454	4454	19 (7) Renewable energy credits procured from new
4455	4455	20 photovoltaic projects or new distributed renewable energy
4456	4456	21 generation devices under this Section after June 1, 2017
4457	4457	22 (the effective date of Public Act 99-906) must be procured
4458	4458	23 from devices installed by a qualified person in compliance
4459	4459	24 with the requirements of Section 16-128A of the Public
4460	4460	25 Utilities Act and any rules or regulations adopted
4461	4461	26 thereunder.
4462	4462
4463	4463
4464	4464
4465	4465
4466	4466
4467	4467	HB5514 - 123 - LRB103 39335 CES 69496 b
4468	4468
4469	4469
4470	4470	HB5514- 124 -LRB103 39335 CES 69496 b HB5514 - 124 - LRB103 39335 CES 69496 b
4471	4471	HB5514 - 124 - LRB103 39335 CES 69496 b
4472	4472	1 In meeting the renewable energy requirements of this
4473	4473	2 subsection (c), to the extent feasible and consistent with
4474	4474	3 State and federal law, the renewable energy credit
4475	4475	4 procurements, Adjustable Block solar program, and
4476	4476	5 community renewable generation program shall provide
4477	4477	6 employment opportunities for all segments of the
4478	4478	7 population and workforce, including minority-owned and
4479	4479	8 female-owned business enterprises, and shall not,
4480	4480	9 consistent with State and federal law, discriminate based
4481	4481	10 on race or socioeconomic status.
4482	4482	11 (c-5) Procurement of renewable energy credits from new
4483	4483	12 renewable energy facilities installed at or adjacent to the
4484	4484	13 sites of electric generating facilities that burn or burned
4485	4485	14 coal as their primary fuel source.
4486	4486	15 (1) In addition to the procurement of renewable energy
4487	4487	16 credits pursuant to long-term renewable resources
4488	4488	17 procurement plans in accordance with subsection (c) of
4489	4489	18 this Section and Section 16-111.5 of the Public Utilities
4490	4490	19 Act, the Agency shall conduct procurement events in
4491	4491	20 accordance with this subsection (c-5) for the procurement
4492	4492	21 by electric utilities that served more than 300,000 retail
4493	4493	22 customers in this State as of January 1, 2019 of renewable
4494	4494	23 energy credits from new renewable energy facilities to be
4495	4495	24 installed at or adjacent to the sites of electric
4496	4496	25 generating facilities that, as of January 1, 2016, burned
4497	4497	26 coal as their primary fuel source and meet the other
4498	4498
4499	4499
4500	4500
4501	4501
4502	4502
4503	4503	HB5514 - 124 - LRB103 39335 CES 69496 b
4504	4504
4505	4505
4506	4506	HB5514- 125 -LRB103 39335 CES 69496 b HB5514 - 125 - LRB103 39335 CES 69496 b
4507	4507	HB5514 - 125 - LRB103 39335 CES 69496 b
4508	4508	1 criteria specified in this subsection (c-5). For purposes
4509	4509	2 of this subsection (c-5), "new renewable energy facility"
4510	4510	3 means a new utility-scale solar project as defined in this
4511	4511	4 Section 1-75. The renewable energy credits procured
4512	4512	5 pursuant to this subsection (c-5) may be included or
4513	4513	6 counted for purposes of compliance with the amounts of
4514	4514	7 renewable energy credits required to be procured pursuant
4515	4515	8 to subsection (c) of this Section to the extent that there
4516	4516	9 are otherwise shortfalls in compliance with such
4517	4517	10 requirements. The procurement of renewable energy credits
4518	4518	11 by electric utilities pursuant to this subsection (c-5)
4519	4519	12 shall be funded solely by revenues collected from the Coal
4520	4520	13 to Solar and Energy Storage Initiative Charge provided for
4521	4521	14 in this subsection (c-5) and subsection (i-5) of Section
4522	4522	15 16-108 of the Public Utilities Act, shall not be funded by
4523	4523	16 revenues collected through any of the other funding
4524	4524	17 mechanisms provided for in subsection (c) of this Section,
4525	4525	18 and shall not be subject to the limitation imposed by
4526	4526	19 subsection (c) on charges to retail customers for costs to
4527	4527	20 procure renewable energy resources pursuant to subsection
4528	4528	21 (c), and shall not be subject to any other requirements or
4529	4529	22 limitations of subsection (c).
4530	4530	23 (2) The Agency shall conduct 2 procurement events to
4531	4531	24 select owners of electric generating facilities meeting
4532	4532	25 the eligibility criteria specified in this subsection
4533	4533	26 (c-5) to enter into long-term contracts to sell renewable
4534	4534
4535	4535
4536	4536
4537	4537
4538	4538
4539	4539	HB5514 - 125 - LRB103 39335 CES 69496 b
4540	4540
4541	4541
4542	4542	HB5514- 126 -LRB103 39335 CES 69496 b HB5514 - 126 - LRB103 39335 CES 69496 b
4543	4543	HB5514 - 126 - LRB103 39335 CES 69496 b
4544	4544	1 energy credits to electric utilities serving more than
4545	4545	2 300,000 retail customers in this State as of January 1,
4546	4546	3 2019. The first procurement event shall be conducted no
4547	4547	4 later than March 31, 2022, unless the Agency elects to
4548	4548	5 delay it, until no later than May 1, 2022, due to its
4549	4549	6 overall volume of work, and shall be to select owners of
4550	4550	7 electric generating facilities located in this State and
4551	4551	8 south of federal Interstate Highway 80 that meet the
4552	4552	9 eligibility criteria specified in this subsection (c-5).
4553	4553	10 The second procurement event shall be conducted no sooner
4554	4554	11 than September 30, 2022 and no later than October 31, 2022
4555	4555	12 and shall be to select owners of electric generating
4556	4556	13 facilities located anywhere in this State that meet the
4557	4557	14 eligibility criteria specified in this subsection (c-5).
4558	4558	15 The Agency shall establish and announce a time period,
4559	4559	16 which shall begin no later than 30 days prior to the
4560	4560	17 scheduled date for the procurement event, during which
4561	4561	18 applicants may submit applications to be selected as
4562	4562	19 suppliers of renewable energy credits pursuant to this
4563	4563	20 subsection (c-5). The eligibility criteria for selection
4564	4564	21 as a supplier of renewable energy credits pursuant to this
4565	4565	22 subsection (c-5) shall be as follows:
4566	4566	23 (A) The applicant owns an electric generating
4567	4567	24 facility located in this State that: (i) as of January
4568	4568	25 1, 2016, burned coal as its primary fuel to generate
4569	4569	26 electricity; and (ii) has, or had prior to retirement,
4570	4570
4571	4571
4572	4572
4573	4573
4574	4574
4575	4575	HB5514 - 126 - LRB103 39335 CES 69496 b
4576	4576
4577	4577
4578	4578	HB5514- 127 -LRB103 39335 CES 69496 b HB5514 - 127 - LRB103 39335 CES 69496 b
4579	4579	HB5514 - 127 - LRB103 39335 CES 69496 b
4580	4580	1 an electric generating capacity of at least 150
4581	4581	2 megawatts. The electric generating facility can be
4582	4582	3 either: (i) retired as of the date of the procurement
4583	4583	4 event; or (ii) still operating as of the date of the
4584	4584	5 procurement event.
4585	4585	6 (B) The applicant is not (i) an electric
4586	4586	7 cooperative as defined in Section 3-119 of the Public
4587	4587	8 Utilities Act, or (ii) an entity described in
4588	4588	9 subsection (b)(1) of Section 3-105 of the Public
4589	4589	10 Utilities Act, or an association or consortium of or
4590	4590	11 an entity owned by entities described in (i) or (ii);
4591	4591	12 and the coal-fueled electric generating facility was
4592	4592	13 at one time owned, in whole or in part, by a public
4593	4593	14 utility as defined in Section 3-105 of the Public
4594	4594	15 Utilities Act.
4595	4595	16 (C) If participating in the first procurement
4596	4596	17 event, the applicant proposes and commits to construct
4597	4597	18 and operate, at the site, and if necessary for
4598	4598	19 sufficient space on property adjacent to the existing
4599	4599	20 property, at which the electric generating facility
4600	4600	21 identified in paragraph (A) is located: (i) a new
4601	4601	22 renewable energy facility of at least 20 megawatts but
4602	4602	23 no more than 100 megawatts of electric generating
4603	4603	24 capacity, and (ii) an energy storage facility having a
4604	4604	25 storage capacity equal to at least 2 megawatts and at
4605	4605	26 most 10 megawatts. If participating in the second
4606	4606
4607	4607
4608	4608
4609	4609
4610	4610
4611	4611	HB5514 - 127 - LRB103 39335 CES 69496 b
4612	4612
4613	4613
4614	4614	HB5514- 128 -LRB103 39335 CES 69496 b HB5514 - 128 - LRB103 39335 CES 69496 b
4615	4615	HB5514 - 128 - LRB103 39335 CES 69496 b
4616	4616	1 procurement event, the applicant proposes and commits
4617	4617	2 to construct and operate, at the site, and if
4618	4618	3 necessary for sufficient space on property adjacent to
4619	4619	4 the existing property, at which the electric
4620	4620	5 generating facility identified in paragraph (A) is
4621	4621	6 located: (i) a new renewable energy facility of at
4622	4622	7 least 5 megawatts but no more than 20 megawatts of
4623	4623	8 electric generating capacity, and (ii) an energy
4624	4624	9 storage facility having a storage capacity equal to at
4625	4625	10 least 0.5 megawatts and at most one megawatt.
4626	4626	11 (D) The applicant agrees that the new renewable
4627	4627	12 energy facility and the energy storage facility will
4628	4628	13 be constructed or installed by a qualified entity or
4629	4629	14 entities in compliance with the requirements of
4630	4630	15 subsection (g) of Section 16-128A of the Public
4631	4631	16 Utilities Act and any rules adopted thereunder.
4632	4632	17 (E) The applicant agrees that personnel operating
4633	4633	18 the new renewable energy facility and the energy
4634	4634	19 storage facility will have the requisite skills,
4635	4635	20 knowledge, training, experience, and competence, which
4636	4636	21 may be demonstrated by completion or current
4637	4637	22 participation and ultimate completion by employees of
4638	4638	23 an accredited or otherwise recognized apprenticeship
4639	4639	24 program for the employee's particular craft, trade, or
4640	4640	25 skill, including through training and education
4641	4641	26 courses and opportunities offered by the owner to
4642	4642
4643	4643
4644	4644
4645	4645
4646	4646
4647	4647	HB5514 - 128 - LRB103 39335 CES 69496 b
4648	4648
4649	4649
4650	4650	HB5514- 129 -LRB103 39335 CES 69496 b HB5514 - 129 - LRB103 39335 CES 69496 b
4651	4651	HB5514 - 129 - LRB103 39335 CES 69496 b
4652	4652	1 employees of the coal-fueled electric generating
4653	4653	2 facility or by previous employment experience
4654	4654	3 performing the employee's particular work skill or
4655	4655	4 function.
4656	4656	5 (F) The applicant commits that not less than the
4657	4657	6 prevailing wage, as determined pursuant to the
4658	4658	7 Prevailing Wage Act, will be paid to the applicant's
4659	4659	8 employees engaged in construction activities
4660	4660	9 associated with the new renewable energy facility and
4661	4661	10 the new energy storage facility and to the employees
4662	4662	11 of applicant's contractors engaged in construction
4663	4663	12 activities associated with the new renewable energy
4664	4664	13 facility and the new energy storage facility, and
4665	4665	14 that, on or before the commercial operation date of
4666	4666	15 the new renewable energy facility, the applicant shall
4667	4667	16 file a report with the Agency certifying that the
4668	4668	17 requirements of this subparagraph (F) have been met.
4669	4669	18 (G) The applicant commits that if selected, it
4670	4670	19 will negotiate a project labor agreement for the
4671	4671	20 construction of the new renewable energy facility and
4672	4672	21 associated energy storage facility that includes
4673	4673	22 provisions requiring the parties to the agreement to
4674	4674	23 work together to establish diversity threshold
4675	4675	24 requirements and to ensure best efforts to meet
4676	4676	25 diversity targets, improve diversity at the applicable
4677	4677	26 job site, create diverse apprenticeship opportunities,
4678	4678
4679	4679
4680	4680
4681	4681
4682	4682
4683	4683	HB5514 - 129 - LRB103 39335 CES 69496 b
4684	4684
4685	4685
4686	4686	HB5514- 130 -LRB103 39335 CES 69496 b HB5514 - 130 - LRB103 39335 CES 69496 b
4687	4687	HB5514 - 130 - LRB103 39335 CES 69496 b
4688	4688	1 and create opportunities to employ former coal-fired
4689	4689	2 power plant workers.
4690	4690	3 (H) The applicant commits to enter into a contract
4691	4691	4 or contracts for the applicable duration to provide
4692	4692	5 specified numbers of renewable energy credits each
4693	4693	6 year from the new renewable energy facility to
4694	4694	7 electric utilities that served more than 300,000
4695	4695	8 retail customers in this State as of January 1, 2019,
4696	4696	9 at a price of $30 per renewable energy credit. The
4697	4697	10 price per renewable energy credit shall be fixed at
4698	4698	11 $30 for the applicable duration and the renewable
4699	4699	12 energy credits shall not be indexed renewable energy
4700	4700	13 credits as provided for in item (v) of subparagraph
4701	4701	14 (G) of paragraph (1) of subsection (c) of Section 1-75
4702	4702	15 of this Act. The applicable duration of each contract
4703	4703	16 shall be 20 years, unless the applicant is physically
4704	4704	17 interconnected to the PJM Interconnection, LLC
4705	4705	18 transmission grid and had a generating capacity of at
4706	4706	19 least 1,200 megawatts as of January 1, 2021, in which
4707	4707	20 case the applicable duration of the contract shall be
4708	4708	21 15 years.
4709	4709	22 (I) The applicant's application is certified by an
4710	4710	23 officer of the applicant and by an officer of the
4711	4711	24 applicant's ultimate parent company, if any.
4712	4712	25 (3) An applicant may submit applications to contract
4713	4713	26 to supply renewable energy credits from more than one new
4714	4714
4715	4715
4716	4716
4717	4717
4718	4718
4719	4719	HB5514 - 130 - LRB103 39335 CES 69496 b
4720	4720
4721	4721
4722	4722	HB5514- 131 -LRB103 39335 CES 69496 b HB5514 - 131 - LRB103 39335 CES 69496 b
4723	4723	HB5514 - 131 - LRB103 39335 CES 69496 b
4724	4724	1 renewable energy facility to be constructed at or adjacent
4725	4725	2 to one or more qualifying electric generating facilities
4726	4726	3 owned by the applicant. The Agency may select new
4727	4727	4 renewable energy facilities to be located at or adjacent
4728	4728	5 to the sites of more than one qualifying electric
4729	4729	6 generation facility owned by an applicant to contract with
4730	4730	7 electric utilities to supply renewable energy credits from
4731	4731	8 such facilities.
4732	4732	9 (4) The Agency shall assess fees to each applicant to
4733	4733	10 recover the Agency's costs incurred in receiving and
4734	4734	11 evaluating applications, conducting the procurement event,
4735	4735	12 developing contracts for sale, delivery and purchase of
4736	4736	13 renewable energy credits, and monitoring the
4737	4737	14 administration of such contracts, as provided for in this
4738	4738	15 subsection (c-5), including fees paid to a procurement
4739	4739	16 administrator retained by the Agency for one or more of
4740	4740	17 these purposes.
4741	4741	18 (5) The Agency shall select the applicants and the new
4742	4742	19 renewable energy facilities to contract with electric
4743	4743	20 utilities to supply renewable energy credits in accordance
4744	4744	21 with this subsection (c-5). In the first procurement
4745	4745	22 event, the Agency shall select applicants and new
4746	4746	23 renewable energy facilities to supply renewable energy
4747	4747	24 credits, at a price of $30 per renewable energy credit,
4748	4748	25 aggregating to no less than 400,000 renewable energy
4749	4749	26 credits per year for the applicable duration, assuming
4750	4750
4751	4751
4752	4752
4753	4753
4754	4754
4755	4755	HB5514 - 131 - LRB103 39335 CES 69496 b
4756	4756
4757	4757
4758	4758	HB5514- 132 -LRB103 39335 CES 69496 b HB5514 - 132 - LRB103 39335 CES 69496 b
4759	4759	HB5514 - 132 - LRB103 39335 CES 69496 b
4760	4760	1 sufficient qualifying applications to supply, in the
4761	4761	2 aggregate, at least that amount of renewable energy
4762	4762	3 credits per year; and not more than 580,000 renewable
4763	4763	4 energy credits per year for the applicable duration. In
4764	4764	5 the second procurement event, the Agency shall select
4765	4765	6 applicants and new renewable energy facilities to supply
4766	4766	7 renewable energy credits, at a price of $30 per renewable
4767	4767	8 energy credit, aggregating to no more than 625,000
4768	4768	9 renewable energy credits per year less the amount of
4769	4769	10 renewable energy credits each year contracted for as a
4770	4770	11 result of the first procurement event, for the applicable
4771	4771	12 durations. The number of renewable energy credits to be
4772	4772	13 procured as specified in this paragraph (5) shall not be
4773	4773	14 reduced based on renewable energy credits procured in the
4774	4774	15 self-direct renewable energy credit compliance program
4775	4775	16 established pursuant to subparagraph (R) of paragraph (1)
4776	4776	17 of subsection (c) of Section 1-75.
4777	4777	18 (6) The obligation to purchase renewable energy
4778	4778	19 credits from the applicants and their new renewable energy
4779	4779	20 facilities selected by the Agency shall be allocated to
4780	4780	21 the electric utilities based on their respective
4781	4781	22 percentages of kilowatthours delivered to delivery
4782	4782	23 services customers to the aggregate kilowatthour
4783	4783	24 deliveries by the electric utilities to delivery services
4784	4784	25 customers for the year ended December 31, 2021. In order
4785	4785	26 to achieve these allocation percentages between or among
4786	4786
4787	4787
4788	4788
4789	4789
4790	4790
4791	4791	HB5514 - 132 - LRB103 39335 CES 69496 b
4792	4792
4793	4793
4794	4794	HB5514- 133 -LRB103 39335 CES 69496 b HB5514 - 133 - LRB103 39335 CES 69496 b
4795	4795	HB5514 - 133 - LRB103 39335 CES 69496 b
4796	4796	1 the electric utilities, the Agency shall require each
4797	4797	2 applicant that is selected in the procurement event to
4798	4798	3 enter into a contract with each electric utility for the
4799	4799	4 sale and purchase of renewable energy credits from each
4800	4800	5 new renewable energy facility to be constructed and
4801	4801	6 operated by the applicant, with the sale and purchase
4802	4802	7 obligations under the contracts to aggregate to the total
4803	4803	8 number of renewable energy credits per year to be supplied
4804	4804	9 by the applicant from the new renewable energy facility.
4805	4805	10 (7) The Agency shall submit its proposed selection of
4806	4806	11 applicants, new renewable energy facilities to be
4807	4807	12 constructed, and renewable energy credit amounts for each
4808	4808	13 procurement event to the Commission for approval. The
4809	4809	14 Commission shall, within 2 business days after receipt of
4810	4810	15 the Agency's proposed selections, approve the proposed
4811	4811	16 selections if it determines that the applicants and the
4812	4812	17 new renewable energy facilities to be constructed meet the
4813	4813	18 selection criteria set forth in this subsection (c-5) and
4814	4814	19 that the Agency seeks approval for contracts of applicable
4815	4815	20 durations aggregating to no more than the maximum amount
4816	4816	21 of renewable energy credits per year authorized by this
4817	4817	22 subsection (c-5) for the procurement event, at a price of
4818	4818	23 $30 per renewable energy credit.
4819	4819	24 (8) The Agency, in conjunction with its procurement
4820	4820	25 administrator if one is retained, the electric utilities,
4821	4821	26 and potential applicants for contracts to produce and
4822	4822
4823	4823
4824	4824
4825	4825
4826	4826
4827	4827	HB5514 - 133 - LRB103 39335 CES 69496 b
4828	4828
4829	4829
4830	4830	HB5514- 134 -LRB103 39335 CES 69496 b HB5514 - 134 - LRB103 39335 CES 69496 b
4831	4831	HB5514 - 134 - LRB103 39335 CES 69496 b
4832	4832	1 supply renewable energy credits pursuant to this
4833	4833	2 subsection (c-5), shall develop a standard form contract
4834	4834	3 for the sale, delivery and purchase of renewable energy
4835	4835	4 credits pursuant to this subsection (c-5). Each contract
4836	4836	5 resulting from the first procurement event shall allow for
4837	4837	6 a commercial operation date for the new renewable energy
4838	4838	7 facility of either June 1, 2023 or June 1, 2024, with such
4839	4839	8 dates subject to adjustment as provided in this paragraph.
4840	4840	9 Each contract resulting from the second procurement event
4841	4841	10 shall provide for a commercial operation date on June 1
4842	4842	11 next occurring up to 48 months after execution of the
4843	4843	12 contract. Each contract shall provide that the owner shall
4844	4844	13 receive payments for renewable energy credits for the
4845	4845	14 applicable durations beginning with the commercial
4846	4846	15 operation date of the new renewable energy facility. The
4847	4847	16 form contract shall provide for adjustments to the
4848	4848	17 commercial operation and payment start dates as needed due
4849	4849	18 to any delays in completing the procurement and
4850	4850	19 contracting processes, in finalizing interconnection
4851	4851	20 agreements and installing interconnection facilities, and
4852	4852	21 in obtaining other necessary governmental permits and
4853	4853	22 approvals. The form contract shall be, to the maximum
4854	4854	23 extent possible, consistent with standard electric
4855	4855	24 industry contracts for sale, delivery, and purchase of
4856	4856	25 renewable energy credits while taking into account the
4857	4857	26 specific requirements of this subsection (c-5). The form
4858	4858
4859	4859
4860	4860
4861	4861
4862	4862
4863	4863	HB5514 - 134 - LRB103 39335 CES 69496 b
4864	4864
4865	4865
4866	4866	HB5514- 135 -LRB103 39335 CES 69496 b HB5514 - 135 - LRB103 39335 CES 69496 b
4867	4867	HB5514 - 135 - LRB103 39335 CES 69496 b
4868	4868	1 contract shall provide for over-delivery and
4869	4869	2 under-delivery of renewable energy credits within
4870	4870	3 reasonable ranges during each 12-month period and penalty,
4871	4871	4 default, and enforcement provisions for failure of the
4872	4872	5 selling party to deliver renewable energy credits as
4873	4873	6 specified in the contract and to comply with the
4874	4874	7 requirements of this subsection (c-5). The standard form
4875	4875	8 contract shall specify that all renewable energy credits
4876	4876	9 delivered to the electric utility pursuant to the contract
4877	4877	10 shall be retired. The Agency shall make the proposed
4878	4878	11 contracts available for a reasonable period for comment by
4879	4879	12 potential applicants, and shall publish the final form
4880	4880	13 contract at least 30 days before the date of the first
4881	4881	14 procurement event.
4882	4882	15 (9) Coal to Solar and Energy Storage Initiative
4883	4883	16 Charge.
4884	4884	17 (A) By no later than July 1, 2022, each electric
4885	4885	18 utility that served more than 300,000 retail customers
4886	4886	19 in this State as of January 1, 2019 shall file a tariff
4887	4887	20 with the Commission for the billing and collection of
4888	4888	21 a Coal to Solar and Energy Storage Initiative Charge
4889	4889	22 in accordance with subsection (i-5) of Section 16-108
4890	4890	23 of the Public Utilities Act, with such tariff to be
4891	4891	24 effective, following review and approval or
4892	4892	25 modification by the Commission, beginning January 1,
4893	4893	26 2023. The tariff shall provide for the calculation and
4894	4894
4895	4895
4896	4896
4897	4897
4898	4898
4899	4899	HB5514 - 135 - LRB103 39335 CES 69496 b
4900	4900
4901	4901
4902	4902	HB5514- 136 -LRB103 39335 CES 69496 b HB5514 - 136 - LRB103 39335 CES 69496 b
4903	4903	HB5514 - 136 - LRB103 39335 CES 69496 b
4904	4904	1 setting of the electric utility's Coal to Solar and
4905	4905	2 Energy Storage Initiative Charge to collect revenues
4906	4906	3 estimated to be sufficient, in the aggregate, (i) to
4907	4907	4 enable the electric utility to pay for the renewable
4908	4908	5 energy credits it has contracted to purchase in the
4909	4909	6 delivery year beginning June 1, 2023 and each delivery
4910	4910	7 year thereafter from new renewable energy facilities
4911	4911	8 located at the sites of qualifying electric generating
4912	4912	9 facilities, and (ii) to fund the grant payments to be
4913	4913	10 made in each delivery year by the Department of
4914	4914	11 Commerce and Economic Opportunity, or any successor
4915	4915	12 department or agency, which shall be referred to in
4916	4916	13 this subsection (c-5) as the Department, pursuant to
4917	4917	14 paragraph (10) of this subsection (c-5). The electric
4918	4918	15 utility's tariff shall provide for the billing and
4919	4919	16 collection of the Coal to Solar and Energy Storage
4920	4920	17 Initiative Charge on each kilowatthour of electricity
4921	4921	18 delivered to its delivery services customers within
4922	4922	19 its service territory and shall provide for an annual
4923	4923	20 reconciliation of revenues collected with actual
4924	4924	21 costs, in accordance with subsection (i-5) of Section
4925	4925	22 16-108 of the Public Utilities Act.
4926	4926	23 (B) Each electric utility shall remit on a monthly
4927	4927	24 basis to the State Treasurer, for deposit in the Coal
4928	4928	25 to Solar and Energy Storage Initiative Fund provided
4929	4929	26 for in this subsection (c-5), the electric utility's
4930	4930
4931	4931
4932	4932
4933	4933
4934	4934
4935	4935	HB5514 - 136 - LRB103 39335 CES 69496 b
4936	4936
4937	4937
4938	4938	HB5514- 137 -LRB103 39335 CES 69496 b HB5514 - 137 - LRB103 39335 CES 69496 b
4939	4939	HB5514 - 137 - LRB103 39335 CES 69496 b
4940	4940	1 collections of the Coal to Solar and Energy Storage
4941	4941	2 Initiative Charge in the amount estimated to be needed
4942	4942	3 by the Department for grant payments pursuant to grant
4943	4943	4 contracts entered into by the Department pursuant to
4944	4944	5 paragraph (10) of this subsection (c-5).
4945	4945	6 (10) Coal to Solar and Energy Storage Initiative Fund.
4946	4946	7 (A) The Coal to Solar and Energy Storage
4947	4947	8 Initiative Fund is established as a special fund in
4948	4948	9 the State treasury. The Coal to Solar and Energy
4949	4949	10 Storage Initiative Fund is authorized to receive, by
4950	4950	11 statutory deposit, that portion specified in item (B)
4951	4951	12 of paragraph (9) of this subsection (c-5) of moneys
4952	4952	13 collected by electric utilities through imposition of
4953	4953	14 the Coal to Solar and Energy Storage Initiative Charge
4954	4954	15 required by this subsection (c-5). The Coal to Solar
4955	4955	16 and Energy Storage Initiative Fund shall be
4956	4956	17 administered by the Department to provide grants to
4957	4957	18 support the installation and operation of energy
4958	4958	19 storage facilities at the sites of qualifying electric
4959	4959	20 generating facilities meeting the criteria specified
4960	4960	21 in this paragraph (10).
4961	4961	22 (B) The Coal to Solar and Energy Storage
4962	4962	23 Initiative Fund shall not be subject to sweeps,
4963	4963	24 administrative charges, or chargebacks, including, but
4964	4964	25 not limited to, those authorized under Section 8h of
4965	4965	26 the State Finance Act, that would in any way result in
4966	4966
4967	4967
4968	4968
4969	4969
4970	4970
4971	4971	HB5514 - 137 - LRB103 39335 CES 69496 b
4972	4972
4973	4973
4974	4974	HB5514- 138 -LRB103 39335 CES 69496 b HB5514 - 138 - LRB103 39335 CES 69496 b
4975	4975	HB5514 - 138 - LRB103 39335 CES 69496 b
4976	4976	1 the transfer of those funds from the Coal to Solar and
4977	4977	2 Energy Storage Initiative Fund to any other fund of
4978	4978	3 this State or in having any such funds utilized for any
4979	4979	4 purpose other than the express purposes set forth in
4980	4980	5 this paragraph (10).
4981	4981	6 (C) The Department shall utilize up to
4982	4982	7 $280,500,000 in the Coal to Solar and Energy Storage
4983	4983	8 Initiative Fund for grants, assuming sufficient
4984	4984	9 qualifying applicants, to support installation of
4985	4985	10 energy storage facilities at the sites of up to 3
4986	4986	11 qualifying electric generating facilities located in
4987	4987	12 the Midcontinent Independent System Operator, Inc.,
4988	4988	13 region in Illinois and the sites of up to 2 qualifying
4989	4989	14 electric generating facilities located in the PJM
4990	4990	15 Interconnection, LLC region in Illinois that meet the
4991	4991	16 criteria set forth in this subparagraph (C). The
4992	4992	17 criteria for receipt of a grant pursuant to this
4993	4993	18 subparagraph (C) are as follows:
4994	4994	19 (1) the electric generating facility at the
4995	4995	20 site has, or had prior to retirement, an electric
4996	4996	21 generating capacity of at least 150 megawatts;
4997	4997	22 (2) the electric generating facility burns (or
4998	4998	23 burned prior to retirement) coal as its primary
4999	4999	24 source of fuel;
5000	5000	25 (3) if the electric generating facility is
5001	5001	26 retired, it was retired subsequent to January 1,
5002	5002
5003	5003
5004	5004
5005	5005
5006	5006
5007	5007	HB5514 - 138 - LRB103 39335 CES 69496 b
5008	5008
5009	5009
5010	5010	HB5514- 139 -LRB103 39335 CES 69496 b HB5514 - 139 - LRB103 39335 CES 69496 b
5011	5011	HB5514 - 139 - LRB103 39335 CES 69496 b
5012	5012	1 2016;
5013	5013	2 (4) the owner of the electric generating
5014	5014	3 facility has not been selected by the Agency
5015	5015	4 pursuant to this subsection (c-5) of this Section
5016	5016	5 to enter into a contract to sell renewable energy
5017	5017	6 credits to one or more electric utilities from a
5018	5018	7 new renewable energy facility located or to be
5019	5019	8 located at or adjacent to the site at which the
5020	5020	9 electric generating facility is located;
5021	5021	10 (5) the electric generating facility located
5022	5022	11 at the site was at one time owned, in whole or in
5023	5023	12 part, by a public utility as defined in Section
5024	5024	13 3-105 of the Public Utilities Act;
5025	5025	14 (6) the electric generating facility at the
5026	5026	15 site is not owned by (i) an electric cooperative
5027	5027	16 as defined in Section 3-119 of the Public
5028	5028	17 Utilities Act, or (ii) an entity described in
5029	5029	18 subsection (b)(1) of Section 3-105 of the Public
5030	5030	19 Utilities Act, or an association or consortium of
5031	5031	20 or an entity owned by entities described in items
5032	5032	21 (i) or (ii);
5033	5033	22 (7) the proposed energy storage facility at
5034	5034	23 the site will have energy storage capacity of at
5035	5035	24 least 37 megawatts;
5036	5036	25 (8) the owner commits to place the energy
5037	5037	26 storage facility into commercial operation on
5038	5038
5039	5039
5040	5040
5041	5041
5042	5042
5043	5043	HB5514 - 139 - LRB103 39335 CES 69496 b
5044	5044
5045	5045
5046	5046	HB5514- 140 -LRB103 39335 CES 69496 b HB5514 - 140 - LRB103 39335 CES 69496 b
5047	5047	HB5514 - 140 - LRB103 39335 CES 69496 b
5048	5048	1 either June 1, 2023, June 1, 2024, or June 1, 2025,
5049	5049	2 with such date subject to adjustment as needed due
5050	5050	3 to any delays in completing the grant contracting
5051	5051	4 process, in finalizing interconnection agreements
5052	5052	5 and in installing interconnection facilities, and
5053	5053	6 in obtaining necessary governmental permits and
5054	5054	7 approvals;
5055	5055	8 (9) the owner agrees that the new energy
5056	5056	9 storage facility will be constructed or installed
5057	5057	10 by a qualified entity or entities consistent with
5058	5058	11 the requirements of subsection (g) of Section
5059	5059	12 16-128A of the Public Utilities Act and any rules
5060	5060	13 adopted under that Section;
5061	5061	14 (10) the owner agrees that personnel operating
5062	5062	15 the energy storage facility will have the
5063	5063	16 requisite skills, knowledge, training, experience,
5064	5064	17 and competence, which may be demonstrated by
5065	5065	18 completion or current participation and ultimate
5066	5066	19 completion by employees of an accredited or
5067	5067	20 otherwise recognized apprenticeship program for
5068	5068	21 the employee's particular craft, trade, or skill,
5069	5069	22 including through training and education courses
5070	5070	23 and opportunities offered by the owner to
5071	5071	24 employees of the coal-fueled electric generating
5072	5072	25 facility or by previous employment experience
5073	5073	26 performing the employee's particular work skill or
5074	5074
5075	5075
5076	5076
5077	5077
5078	5078
5079	5079	HB5514 - 140 - LRB103 39335 CES 69496 b
5080	5080
5081	5081
5082	5082	HB5514- 141 -LRB103 39335 CES 69496 b HB5514 - 141 - LRB103 39335 CES 69496 b
5083	5083	HB5514 - 141 - LRB103 39335 CES 69496 b
5084	5084	1 function;
5085	5085	2 (11) the owner commits that not less than the
5086	5086	3 prevailing wage, as determined pursuant to the
5087	5087	4 Prevailing Wage Act, will be paid to the owner's
5088	5088	5 employees engaged in construction activities
5089	5089	6 associated with the new energy storage facility
5090	5090	7 and to the employees of the owner's contractors
5091	5091	8 engaged in construction activities associated with
5092	5092	9 the new energy storage facility, and that, on or
5093	5093	10 before the commercial operation date of the new
5094	5094	11 energy storage facility, the owner shall file a
5095	5095	12 report with the Department certifying that the
5096	5096	13 requirements of this subparagraph (11) have been
5097	5097	14 met; and
5098	5098	15 (12) the owner commits that if selected to
5099	5099	16 receive a grant, it will negotiate a project labor
5100	5100	17 agreement for the construction of the new energy
5101	5101	18 storage facility that includes provisions
5102	5102	19 requiring the parties to the agreement to work
5103	5103	20 together to establish diversity threshold
5104	5104	21 requirements and to ensure best efforts to meet
5105	5105	22 diversity targets, improve diversity at the
5106	5106	23 applicable job site, create diverse apprenticeship
5107	5107	24 opportunities, and create opportunities to employ
5108	5108	25 former coal-fired power plant workers.
5109	5109	26 The Department shall accept applications for this
5110	5110
5111	5111
5112	5112
5113	5113
5114	5114
5115	5115	HB5514 - 141 - LRB103 39335 CES 69496 b
5116	5116
5117	5117
5118	5118	HB5514- 142 -LRB103 39335 CES 69496 b HB5514 - 142 - LRB103 39335 CES 69496 b
5119	5119	HB5514 - 142 - LRB103 39335 CES 69496 b
5120	5120	1 grant program until March 31, 2022 and shall announce
5121	5121	2 the award of grants no later than June 1, 2022. The
5122	5122	3 Department shall make the grant payments to a
5123	5123	4 recipient in equal annual amounts for 10 years
5124	5124	5 following the date the energy storage facility is
5125	5125	6 placed into commercial operation. The annual grant
5126	5126	7 payments to a qualifying energy storage facility shall
5127	5127	8 be $110,000 per megawatt of energy storage capacity,
5128	5128	9 with total annual grant payments pursuant to this
5129	5129	10 subparagraph (C) for qualifying energy storage
5130	5130	11 facilities not to exceed $28,050,000 in any year.
5131	5131	12 (D) Grants of funding for energy storage
5132	5132	13 facilities pursuant to subparagraph (C) of this
5133	5133	14 paragraph (10), from the Coal to Solar and Energy
5134	5134	15 Storage Initiative Fund, shall be memorialized in
5135	5135	16 grant contracts between the Department and the
5136	5136	17 recipient. The grant contracts shall specify the date
5137	5137	18 or dates in each year on which the annual grant
5138	5138	19 payments shall be paid.
5139	5139	20 (E) All disbursements from the Coal to Solar and
5140	5140	21 Energy Storage Initiative Fund shall be made only upon
5141	5141	22 warrants of the Comptroller drawn upon the Treasurer
5142	5142	23 as custodian of the Fund upon vouchers signed by the
5143	5143	24 Director of the Department or by the person or persons
5144	5144	25 designated by the Director of the Department for that
5145	5145	26 purpose. The Comptroller is authorized to draw the
5146	5146
5147	5147
5148	5148
5149	5149
5150	5150
5151	5151	HB5514 - 142 - LRB103 39335 CES 69496 b
5152	5152
5153	5153
5154	5154	HB5514- 143 -LRB103 39335 CES 69496 b HB5514 - 143 - LRB103 39335 CES 69496 b
5155	5155	HB5514 - 143 - LRB103 39335 CES 69496 b
5156	5156	1 warrants upon vouchers so signed. The Treasurer shall
5157	5157	2 accept all written warrants so signed and shall be
5158	5158	3 released from liability for all payments made on those
5159	5159	4 warrants.
5160	5160	5 (11) Diversity, equity, and inclusion plans.
5161	5161	6 (A) Each applicant selected in a procurement event
5162	5162	7 to contract to supply renewable energy credits in
5163	5163	8 accordance with this subsection (c-5) and each owner
5164	5164	9 selected by the Department to receive a grant or
5165	5165	10 grants to support the construction and operation of a
5166	5166	11 new energy storage facility or facilities in
5167	5167	12 accordance with this subsection (c-5) shall, within 60
5168	5168	13 days following the Commission's approval of the
5169	5169	14 applicant to contract to supply renewable energy
5170	5170	15 credits or within 60 days following execution of a
5171	5171	16 grant contract with the Department, as applicable,
5172	5172	17 submit to the Commission a diversity, equity, and
5173	5173	18 inclusion plan setting forth the applicant's or
5174	5174	19 owner's numeric goals for the diversity composition of
5175	5175	20 its supplier entities for the new renewable energy
5176	5176	21 facility or new energy storage facility, as
5177	5177	22 applicable, which shall be referred to for purposes of
5178	5178	23 this paragraph (11) as the project, and the
5179	5179	24 applicant's or owner's action plan and schedule for
5180	5180	25 achieving those goals.
5181	5181	26 (B) For purposes of this paragraph (11), diversity
5182	5182
5183	5183
5184	5184
5185	5185
5186	5186
5187	5187	HB5514 - 143 - LRB103 39335 CES 69496 b
5188	5188
5189	5189
5190	5190	HB5514- 144 -LRB103 39335 CES 69496 b HB5514 - 144 - LRB103 39335 CES 69496 b
5191	5191	HB5514 - 144 - LRB103 39335 CES 69496 b
5192	5192	1 composition shall be based on the percentage, which
5193	5193	2 shall be a minimum of 25%, of eligible expenditures
5194	5194	3 for contract awards for materials and services (which
5195	5195	4 shall be defined in the plan) to business enterprises
5196	5196	5 owned by minority persons, women, or persons with
5197	5197	6 disabilities as defined in Section 2 of the Business
5198	5198	7 Enterprise for Minorities, Women, and Persons with
5199	5199	8 Disabilities Act, to LGBTQ business enterprises, to
5200	5200	9 veteran-owned business enterprises, and to business
5201	5201	10 enterprises located in environmental justice
5202	5202	11 communities. The diversity composition goals of the
5203	5203	12 plan may include eligible expenditures in areas for
5204	5204	13 vendor or supplier opportunities in addition to
5205	5205	14 development and construction of the project, and may
5206	5206	15 exclude from eligible expenditures materials and
5207	5207	16 services with limited market availability, limited
5208	5208	17 production and availability from suppliers in the
5209	5209	18 United States, such as solar panels and storage
5210	5210	19 batteries, and material and services that are subject
5211	5211	20 to critical energy infrastructure or cybersecurity
5212	5212	21 requirements or restrictions. The plan may provide
5213	5213	22 that the diversity composition goals may be met
5214	5214	23 through Tier 1 Direct or Tier 2 subcontracting
5215	5215	24 expenditures or a combination thereof for the project.
5216	5216	25 (C) The plan shall provide for, but not be limited
5217	5217	26 to: (i) internal initiatives, including multi-tier
5218	5218
5219	5219
5220	5220
5221	5221
5222	5222
5223	5223	HB5514 - 144 - LRB103 39335 CES 69496 b
5224	5224
5225	5225
5226	5226	HB5514- 145 -LRB103 39335 CES 69496 b HB5514 - 145 - LRB103 39335 CES 69496 b
5227	5227	HB5514 - 145 - LRB103 39335 CES 69496 b
5228	5228	1 initiatives, by the applicant or owner, or by its
5229	5229	2 engineering, procurement and construction contractor
5230	5230	3 if one is used for the project, which for purposes of
5231	5231	4 this paragraph (11) shall be referred to as the EPC
5232	5232	5 contractor, to enable diverse businesses to be
5233	5233	6 considered fairly for selection to provide materials
5234	5234	7 and services; (ii) requirements for the applicant or
5235	5235	8 owner or its EPC contractor to proactively solicit and
5236	5236	9 utilize diverse businesses to provide materials and
5237	5237	10 services; and (iii) requirements for the applicant or
5238	5238	11 owner or its EPC contractor to hire a diverse
5239	5239	12 workforce for the project. The plan shall include a
5240	5240	13 description of the applicant's or owner's diversity
5241	5241	14 recruiting efforts both for the project and for other
5242	5242	15 areas of the applicant's or owner's business
5243	5243	16 operations. The plan shall provide for the imposition
5244	5244	17 of financial penalties on the applicant's or owner's
5245	5245	18 EPC contractor for failure to exercise best efforts to
5246	5246	19 comply with and execute the EPC contractor's diversity
5247	5247	20 obligations under the plan. The plan may provide for
5248	5248	21 the applicant or owner to set aside a portion of the
5249	5249	22 work on the project to serve as an incubation program
5250	5250	23 for qualified businesses, as specified in the plan,
5251	5251	24 owned by minority persons, women, persons with
5252	5252	25 disabilities, LGBTQ persons, and veterans, and
5253	5253	26 businesses located in environmental justice
5254	5254
5255	5255
5256	5256
5257	5257
5258	5258
5259	5259	HB5514 - 145 - LRB103 39335 CES 69496 b
5260	5260
5261	5261
5262	5262	HB5514- 146 -LRB103 39335 CES 69496 b HB5514 - 146 - LRB103 39335 CES 69496 b
5263	5263	HB5514 - 146 - LRB103 39335 CES 69496 b
5264	5264	1 communities, seeking to enter the renewable energy
5265	5265	2 industry.
5266	5266	3 (D) The applicant or owner may submit a revised or
5267	5267	4 updated plan to the Commission from time to time as
5268	5268	5 circumstances warrant. The applicant or owner shall
5269	5269	6 file annual reports with the Commission detailing the
5270	5270	7 applicant's or owner's progress in implementing its
5271	5271	8 plan and achieving its goals and any modifications the
5272	5272	9 applicant or owner has made to its plan to better
5273	5273	10 achieve its diversity, equity and inclusion goals. The
5274	5274	11 applicant or owner shall file a final report on the
5275	5275	12 fifth June 1 following the commercial operation date
5276	5276	13 of the new renewable energy resource or new energy
5277	5277	14 storage facility, but the applicant or owner shall
5278	5278	15 thereafter continue to be subject to applicable
5279	5279	16 reporting requirements of Section 5-117 of the Public
5280	5280	17 Utilities Act.
5281	5281	18 (c-10) Equity accountability system. It is the purpose of
5282	5282	19 this subsection (c-10) to create an equity accountability
5283	5283	20 system, which includes the minimum equity standards for all
5284	5284	21 renewable energy procurements, the equity category of the
5285	5285	22 Adjustable Block Program, and the equity prioritization for
5286	5286	23 noncompetitive procurements, that is successful in advancing
5287	5287	24 priority access to the clean energy economy for businesses and
5288	5288	25 workers from communities that have been excluded from economic
5289	5289	26 opportunities in the energy sector, have been subject to
5290	5290
5291	5291
5292	5292
5293	5293
5294	5294
5295	5295	HB5514 - 146 - LRB103 39335 CES 69496 b
5296	5296
5297	5297
5298	5298	HB5514- 147 -LRB103 39335 CES 69496 b HB5514 - 147 - LRB103 39335 CES 69496 b
5299	5299	HB5514 - 147 - LRB103 39335 CES 69496 b
5300	5300	1 disproportionate levels of pollution, and have
5301	5301	2 disproportionately experienced negative public health
5302	5302	3 outcomes. Further, it is the purpose of this subsection to
5303	5303	4 ensure that this equity accountability system is successful in
5304	5304	5 advancing equity across Illinois by providing access to the
5305	5305	6 clean energy economy for businesses and workers from
5306	5306	7 communities that have been historically excluded from economic
5307	5307	8 opportunities in the energy sector, have been subject to
5308	5308	9 disproportionate levels of pollution, and have
5309	5309	10 disproportionately experienced negative public health
5310	5310	11 outcomes.
5311	5311	12 (1) Minimum equity standards. The Agency shall create
5312	5312	13 programs with the purpose of increasing access to and
5313	5313	14 development of equity eligible contractors, who are prime
5314	5314	15 contractors and subcontractors, across all of the programs
5315	5315	16 it manages. All applications for renewable energy credit
5316	5316	17 procurements shall comply with specific minimum equity
5317	5317	18 commitments. Starting in the delivery year immediately
5318	5318	19 following the next long-term renewable resources
5319	5319	20 procurement plan, at least 10% of the project workforce
5320	5320	21 for each entity participating in a procurement program
5321	5321	22 outlined in this subsection (c-10) must be done by equity
5322	5322	23 eligible persons or equity eligible contractors. The
5323	5323	24 Agency shall increase the minimum percentage each delivery
5324	5324	25 year thereafter by increments that ensure a statewide
5325	5325	26 average of 30% of the project workforce for each entity
5326	5326
5327	5327
5328	5328
5329	5329
5330	5330
5331	5331	HB5514 - 147 - LRB103 39335 CES 69496 b
5332	5332
5333	5333
5334	5334	HB5514- 148 -LRB103 39335 CES 69496 b HB5514 - 148 - LRB103 39335 CES 69496 b
5335	5335	HB5514 - 148 - LRB103 39335 CES 69496 b
5336	5336	1 participating in a procurement program is done by equity
5337	5337	2 eligible persons or equity eligible contractors by 2030.
5338	5338	3 The Agency shall propose a schedule of percentage
5339	5339	4 increases to the minimum equity standards in its draft
5340	5340	5 revised renewable energy resources procurement plan
5341	5341	6 submitted to the Commission for approval pursuant to
5342	5342	7 paragraph (5) of subsection (b) of Section 16-111.5 of the
5343	5343	8 Public Utilities Act. In determining these annual
5344	5344	9 increases, the Agency shall have the discretion to
5345	5345	10 establish different minimum equity standards for different
5346	5346	11 types of procurements and different regions of the State
5347	5347	12 if the Agency finds that doing so will further the
5348	5348	13 purposes of this subsection (c-10). The proposed schedule
5349	5349	14 of annual increases shall be revisited and updated on an
5350	5350	15 annual basis. Revisions shall be developed with
5351	5351	16 stakeholder input, including from equity eligible persons,
5352	5352	17 equity eligible contractors, clean energy industry
5353	5353	18 representatives, and community-based organizations that
5354	5354	19 work with such persons and contractors.
5355	5355	20 (A) At the start of each delivery year, the Agency
5356	5356	21 shall require a compliance plan from each entity
5357	5357	22 participating in a procurement program of subsection
5358	5358	23 (c) of this Section that demonstrates how they will
5359	5359	24 achieve compliance with the minimum equity standard
5360	5360	25 percentage for work completed in that delivery year.
5361	5361	26 If an entity applies for its approved vendor or
5362	5362
5363	5363
5364	5364
5365	5365
5366	5366
5367	5367	HB5514 - 148 - LRB103 39335 CES 69496 b
5368	5368
5369	5369
5370	5370	HB5514- 149 -LRB103 39335 CES 69496 b HB5514 - 149 - LRB103 39335 CES 69496 b
5371	5371	HB5514 - 149 - LRB103 39335 CES 69496 b
5372	5372	1 designee status between delivery years, the Agency
5373	5373	2 shall require a compliance plan at the time of
5374	5374	3 application.
5375	5375	4 (B) Halfway through each delivery year, the Agency
5376	5376	5 shall require each entity participating in a
5377	5377	6 procurement program to confirm that it will achieve
5378	5378	7 compliance in that delivery year, when applicable. The
5379	5379	8 Agency may offer corrective action plans to entities
5380	5380	9 that are not on track to achieve compliance.
5381	5381	10 (C) At the end of each delivery year, each entity
5382	5382	11 participating and completing work in that delivery
5383	5383	12 year in a procurement program of subsection (c) shall
5384	5384	13 submit a report to the Agency that demonstrates how it
5385	5385	14 achieved compliance with the minimum equity standards
5386	5386	15 percentage for that delivery year.
5387	5387	16 (D) The Agency shall prohibit participation in
5388	5388	17 procurement programs by an approved vendor or
5389	5389	18 designee, as applicable, or entities with which an
5390	5390	19 approved vendor or designee, as applicable, shares a
5391	5391	20 common parent company if an approved vendor or
5392	5392	21 designee, as applicable, failed to meet the minimum
5393	5393	22 equity standards for the prior delivery year. Waivers
5394	5394	23 approved for lack of equity eligible persons or equity
5395	5395	24 eligible contractors in a geographic area of a project
5396	5396	25 shall not count against the approved vendor or
5397	5397	26 designee. The Agency shall offer a corrective action
5398	5398
5399	5399
5400	5400
5401	5401
5402	5402
5403	5403	HB5514 - 149 - LRB103 39335 CES 69496 b
5404	5404
5405	5405
5406	5406	HB5514- 150 -LRB103 39335 CES 69496 b HB5514 - 150 - LRB103 39335 CES 69496 b
5407	5407	HB5514 - 150 - LRB103 39335 CES 69496 b
5408	5408	1 plan for any such entities to assist them in obtaining
5409	5409	2 compliance and shall allow continued access to
5410	5410	3 procurement programs upon an approved vendor or
5411	5411	4 designee demonstrating compliance.
5412	5412	5 (E) The Agency shall pursue efficiencies achieved
5413	5413	6 by combining with other approved vendor or designee
5414	5414	7 reporting.
5415	5415	8 (2) Equity accountability system within the Adjustable
5416	5416	9 Block program. The equity category described in item (vi)
5417	5417	10 of subparagraph (K) of subsection (c) is only available to
5418	5418	11 applicants that are equity eligible contractors.
5419	5419	12 (3) Equity accountability system within competitive
5420	5420	13 procurements. Through its long-term renewable resources
5421	5421	14 procurement plan, the Agency shall develop requirements
5422	5422	15 for ensuring that competitive procurement processes,
5423	5423	16 including utility-scale solar, utility-scale wind, and
5424	5424	17 brownfield site photovoltaic projects, advance the equity
5425	5425	18 goals of this subsection (c-10). Subject to Commission
5426	5426	19 approval, the Agency shall develop bid application
5427	5427	20 requirements and a bid evaluation methodology for ensuring
5428	5428	21 that utilization of equity eligible contractors, whether
5429	5429	22 as bidders or as participants on project development, is
5430	5430	23 optimized, including requiring that winning or successful
5431	5431	24 applicants for utility-scale projects are or will partner
5432	5432	25 with equity eligible contractors and giving preference to
5433	5433	26 bids through which a higher portion of contract value
5434	5434
5435	5435
5436	5436
5437	5437
5438	5438
5439	5439	HB5514 - 150 - LRB103 39335 CES 69496 b
5440	5440
5441	5441
5442	5442	HB5514- 151 -LRB103 39335 CES 69496 b HB5514 - 151 - LRB103 39335 CES 69496 b
5443	5443	HB5514 - 151 - LRB103 39335 CES 69496 b
5444	5444	1 flows to equity eligible contractors. To the extent
5445	5445	2 practicable, entities participating in competitive
5446	5446	3 procurements shall also be required to meet all the equity
5447	5447	4 accountability requirements for approved vendors and their
5448	5448	5 designees under this subsection (c-10). In developing
5449	5449	6 these requirements, the Agency shall also consider whether
5450	5450	7 equity goals can be further advanced through additional
5451	5451	8 measures.
5452	5452	9 (4) In the first revision to the long-term renewable
5453	5453	10 energy resources procurement plan and each revision
5454	5454	11 thereafter, the Agency shall include the following:
5455	5455	12 (A) The current status and number of equity
5456	5456	13 eligible contractors listed in the Energy Workforce
5457	5457	14 Equity Database designed in subsection (c-25),
5458	5458	15 including the number of equity eligible contractors
5459	5459	16 with current certifications as issued by the Agency.
5460	5460	17 (B) A mechanism for measuring, tracking, and
5461	5461	18 reporting project workforce at the approved vendor or
5462	5462	19 designee level, as applicable, which shall include a
5463	5463	20 measurement methodology and records to be made
5464	5464	21 available for audit by the Agency or the Program
5465	5465	22 Administrator.
5466	5466	23 (C) A program for approved vendors, designees,
5467	5467	24 eligible persons, and equity eligible contractors to
5468	5468	25 receive trainings, guidance, and other support from
5469	5469	26 the Agency or its designee regarding the equity
5470	5470
5471	5471
5472	5472
5473	5473
5474	5474
5475	5475	HB5514 - 151 - LRB103 39335 CES 69496 b
5476	5476
5477	5477
5478	5478	HB5514- 152 -LRB103 39335 CES 69496 b HB5514 - 152 - LRB103 39335 CES 69496 b
5479	5479	HB5514 - 152 - LRB103 39335 CES 69496 b
5480	5480	1 category outlined in item (vi) of subparagraph (K) of
5481	5481	2 paragraph (1) of subsection (c) and in meeting the
5482	5482	3 minimum equity standards of this subsection (c-10).
5483	5483	4 (D) A process for certifying equity eligible
5484	5484	5 contractors and equity eligible persons. The
5485	5485	6 certification process shall coordinate with the Energy
5486	5486	7 Workforce Equity Database set forth in subsection
5487	5487	8 (c-25).
5488	5488	9 (E) An application for waiver of the minimum
5489	5489	10 equity standards of this subsection, which the Agency
5490	5490	11 shall have the discretion to grant in rare
5491	5491	12 circumstances. The Agency may grant such a waiver
5492	5492	13 where the applicant provides evidence of significant
5493	5493	14 efforts toward meeting the minimum equity commitment,
5494	5494	15 including: use of the Energy Workforce Equity
5495	5495	16 Database; efforts to hire or contract with entities
5496	5496	17 that hire eligible persons; and efforts to establish
5497	5497	18 contracting relationships with eligible contractors.
5498	5498	19 The Agency shall support applicants in understanding
5499	5499	20 the Energy Workforce Equity Database and other
5500	5500	21 resources for pursuing compliance of the minimum
5501	5501	22 equity standards. Waivers shall be project-specific,
5502	5502	23 unless the Agency deems it necessary to grant a waiver
5503	5503	24 across a portfolio of projects, and in effect for no
5504	5504	25 longer than one year. Any waiver extension or
5505	5505	26 subsequent waiver request from an applicant shall be
5506	5506
5507	5507
5508	5508
5509	5509
5510	5510
5511	5511	HB5514 - 152 - LRB103 39335 CES 69496 b
5512	5512
5513	5513
5514	5514	HB5514- 153 -LRB103 39335 CES 69496 b HB5514 - 153 - LRB103 39335 CES 69496 b
5515	5515	HB5514 - 153 - LRB103 39335 CES 69496 b
5516	5516	1 subject to the requirements of this Section and shall
5517	5517	2 specify efforts made to reach compliance. When
5518	5518	3 considering whether to grant a waiver, and to what
5519	5519	4 extent, the Agency shall consider the degree to which
5520	5520	5 similarly situated applicants have been able to meet
5521	5521	6 these minimum equity commitments. For repeated waiver
5522	5522	7 requests for specific lack of eligible persons or
5523	5523	8 eligible contractors available, the Agency shall make
5524	5524	9 recommendations to target recruitment to add such
5525	5525	10 eligible persons or eligible contractors to the
5526	5526	11 database.
5527	5527	12 (5) The Agency shall collect information about work on
5528	5528	13 projects or portfolios of projects subject to these
5529	5529	14 minimum equity standards to ensure compliance with this
5530	5530	15 subsection (c-10). Reporting in furtherance of this
5531	5531	16 requirement may be combined with other annual reporting
5532	5532	17 requirements. Such reporting shall include proof of
5533	5533	18 certification of each equity eligible contractor or equity
5534	5534	19 eligible person during the applicable time period.
5535	5535	20 (6) The Agency shall keep confidential all information
5536	5536	21 and communication that provides private or personal
5537	5537	22 information.
5538	5538	23 (7) Modifications to the equity accountability system.
5539	5539	24 As part of the update of the long-term renewable resources
5540	5540	25 procurement plan to be initiated in 2023, or sooner if the
5541	5541	26 Agency deems necessary, the Agency shall determine the
5542	5542
5543	5543
5544	5544
5545	5545
5546	5546
5547	5547	HB5514 - 153 - LRB103 39335 CES 69496 b
5548	5548
5549	5549
5550	5550	HB5514- 154 -LRB103 39335 CES 69496 b HB5514 - 154 - LRB103 39335 CES 69496 b
5551	5551	HB5514 - 154 - LRB103 39335 CES 69496 b
5552	5552	1 extent to which the equity accountability system described
5553	5553	2 in this subsection (c-10) has advanced the goals of this
5554	5554	3 amendatory Act of the 102nd General Assembly, including
5555	5555	4 through the inclusion of equity eligible persons and
5556	5556	5 equity eligible contractors in renewable energy credit
5557	5557	6 projects. If the Agency finds that the equity
5558	5558	7 accountability system has failed to meet those goals to
5559	5559	8 its fullest potential, the Agency may revise the following
5560	5560	9 criteria for future Agency procurements: (A) the
5561	5561	10 percentage of project workforce, or other appropriate
5562	5562	11 workforce measure, certified as equity eligible persons or
5563	5563	12 equity eligible contractors; (B) definitions for equity
5564	5564	13 investment eligible persons and equity investment eligible
5565	5565	14 community; and (C) such other modifications necessary to
5566	5566	15 advance the goals of this amendatory Act of the 102nd
5567	5567	16 General Assembly effectively. Such revised criteria may
5568	5568	17 also establish distinct equity accountability systems for
5569	5569	18 different types of procurements or different regions of
5570	5570	19 the State if the Agency finds that doing so will further
5571	5571	20 the purposes of such programs. Revisions shall be
5572	5572	21 developed with stakeholder input, including from equity
5573	5573	22 eligible persons, equity eligible contractors, and
5574	5574	23 community-based organizations that work with such persons
5575	5575	24 and contractors.
5576	5576	25 (c-15) Racial discrimination elimination powers and
5577	5577	26 process.
5578	5578
5579	5579
5580	5580
5581	5581
5582	5582
5583	5583	HB5514 - 154 - LRB103 39335 CES 69496 b
5584	5584
5585	5585
5586	5586	HB5514- 155 -LRB103 39335 CES 69496 b HB5514 - 155 - LRB103 39335 CES 69496 b
5587	5587	HB5514 - 155 - LRB103 39335 CES 69496 b
5588	5588	1 (1) Purpose. It is the purpose of this subsection to
5589	5589	2 empower the Agency and other State actors to remedy racial
5590	5590	3 discrimination in Illinois' clean energy economy as
5591	5591	4 effectively and expediently as possible, including through
5592	5592	5 the use of race-conscious remedies, such as race-conscious
5593	5593	6 contracting and hiring goals, as consistent with State and
5594	5594	7 federal law.
5595	5595	8 (2) Racial disparity and discrimination review
5596	5596	9 process.
5597	5597	10 (A) Within one year after awarding contracts using
5598	5598	11 the equity actions processes established in this
5599	5599	12 Section, the Agency shall publish a report evaluating
5600	5600	13 the effectiveness of the equity actions point criteria
5601	5601	14 of this Section in increasing participation of equity
5602	5602	15 eligible persons and equity eligible contractors. The
5603	5603	16 report shall disaggregate participating workers and
5604	5604	17 contractors by race and ethnicity. The report shall be
5605	5605	18 forwarded to the Governor, the General Assembly, and
5606	5606	19 the Illinois Commerce Commission and be made available
5607	5607	20 to the public.
5608	5608	21 (B) As soon as is practicable thereafter, the
5609	5609	22 Agency, in consultation with the Department of
5610	5610	23 Commerce and Economic Opportunity, Department of
5611	5611	24 Labor, and other agencies that may be relevant, shall
5612	5612	25 commission and publish a disparity and availability
5613	5613	26 study that measures the presence and impact of
5614	5614
5615	5615
5616	5616
5617	5617
5618	5618
5619	5619	HB5514 - 155 - LRB103 39335 CES 69496 b
5620	5620
5621	5621
5622	5622	HB5514- 156 -LRB103 39335 CES 69496 b HB5514 - 156 - LRB103 39335 CES 69496 b
5623	5623	HB5514 - 156 - LRB103 39335 CES 69496 b
5624	5624	1 discrimination on minority businesses and workers in
5625	5625	2 Illinois' clean energy economy. The Agency may hire
5626	5626	3 consultants and experts to conduct the disparity and
5627	5627	4 availability study, with the retention of those
5628	5628	5 consultants and experts exempt from the requirements
5629	5629	6 of Section 20-10 of the Illinois Procurement Code. The
5630	5630	7 Illinois Power Agency shall forward a copy of its
5631	5631	8 findings and recommendations to the Governor, the
5632	5632	9 General Assembly, and the Illinois Commerce
5633	5633	10 Commission. If the disparity and availability study
5634	5634	11 establishes a strong basis in evidence that there is
5635	5635	12 discrimination in Illinois' clean energy economy, the
5636	5636	13 Agency, Department of Commerce and Economic
5637	5637	14 Opportunity, Department of Labor, Department of
5638	5638	15 Corrections, and other appropriate agencies shall take
5639	5639	16 appropriate remedial actions, including race-conscious
5640	5640	17 remedial actions as consistent with State and federal
5641	5641	18 law, to effectively remedy this discrimination. Such
5642	5642	19 remedies may include modification of the equity
5643	5643	20 accountability system as described in subsection
5644	5644	21 (c-10).
5645	5645	22 (c-20) Program data collection.
5646	5646	23 (1) Purpose. Data collection, data analysis, and
5647	5647	24 reporting are critical to ensure that the benefits of the
5648	5648	25 clean energy economy provided to Illinois residents and
5649	5649	26 businesses are equitably distributed across the State. The
5650	5650
5651	5651
5652	5652
5653	5653
5654	5654
5655	5655	HB5514 - 156 - LRB103 39335 CES 69496 b
5656	5656
5657	5657
5658	5658	HB5514- 157 -LRB103 39335 CES 69496 b HB5514 - 157 - LRB103 39335 CES 69496 b
5659	5659	HB5514 - 157 - LRB103 39335 CES 69496 b
5660	5660	1 Agency shall collect data from program applicants in order
5661	5661	2 to track and improve equitable distribution of benefits
5662	5662	3 across Illinois communities for all procurements the
5663	5663	4 Agency conducts. The Agency shall use this data to, among
5664	5664	5 other things, measure any potential impact of racial
5665	5665	6 discrimination on the distribution of benefits and provide
5666	5666	7 information necessary to correct any discrimination
5667	5667	8 through methods consistent with State and federal law.
5668	5668	9 (2) Agency collection of program data. The Agency
5669	5669	10 shall collect demographic and geographic data for each
5670	5670	11 entity awarded contracts under any Agency-administered
5671	5671	12 program.
5672	5672	13 (3) Required information to be collected. The Agency
5673	5673	14 shall collect the following information from applicants
5674	5674	15 and program participants where applicable:
5675	5675	16 (A) demographic information, including racial or
5676	5676	17 ethnic identity for real persons employed, contracted,
5677	5677	18 or subcontracted through the program and owners of
5678	5678	19 businesses or entities that apply to receive renewable
5679	5679	20 energy credits from the Agency;
5680	5680	21 (B) geographic location of the residency of real
5681	5681	22 persons employed, contracted, or subcontracted through
5682	5682	23 the program and geographic location of the
5683	5683	24 headquarters of the business or entity that applies to
5684	5684	25 receive renewable energy credits from the Agency; and
5685	5685	26 (C) any other information the Agency determines is
5686	5686
5687	5687
5688	5688
5689	5689
5690	5690
5691	5691	HB5514 - 157 - LRB103 39335 CES 69496 b
5692	5692
5693	5693
5694	5694	HB5514- 158 -LRB103 39335 CES 69496 b HB5514 - 158 - LRB103 39335 CES 69496 b
5695	5695	HB5514 - 158 - LRB103 39335 CES 69496 b
5696	5696	1 necessary for the purpose of achieving the purpose of
5697	5697	2 this subsection.
5698	5698	3 (4) Publication of collected information. The Agency
5699	5699	4 shall publish, at least annually, information on the
5700	5700	5 demographics of program participants on an aggregate
5701	5701	6 basis.
5702	5702	7 (5) Nothing in this subsection shall be interpreted to
5703	5703	8 limit the authority of the Agency, or other agency or
5704	5704	9 department of the State, to require or collect demographic
5705	5705	10 information from applicants of other State programs.
5706	5706	11 (c-25) Energy Workforce Equity Database.
5707	5707	12 (1) The Agency, in consultation with the Department of
5708	5708	13 Commerce and Economic Opportunity, shall create an Energy
5709	5709	14 Workforce Equity Database, and may contract with a third
5710	5710	15 party to do so ("database program administrator"). If the
5711	5711	16 Department decides to contract with a third party, that
5712	5712	17 third party shall be exempt from the requirements of
5713	5713	18 Section 20-10 of the Illinois Procurement Code. The Energy
5714	5714	19 Workforce Equity Database shall be a searchable database
5715	5715	20 of suppliers, vendors, and subcontractors for clean energy
5716	5716	21 industries that is:
5717	5717	22 (A) publicly accessible;
5718	5718	23 (B) easy for people to find and use;
5719	5719	24 (C) organized by company specialty or field;
5720	5720	25 (D) region-specific; and
5721	5721	26 (E) populated with information including, but not
5722	5722
5723	5723
5724	5724
5725	5725
5726	5726
5727	5727	HB5514 - 158 - LRB103 39335 CES 69496 b
5728	5728
5729	5729
5730	5730	HB5514- 159 -LRB103 39335 CES 69496 b HB5514 - 159 - LRB103 39335 CES 69496 b
5731	5731	HB5514 - 159 - LRB103 39335 CES 69496 b
5732	5732	1 limited to, contacts for suppliers, vendors, or
5733	5733	2 subcontractors who are minority and women-owned
5734	5734	3 business enterprise certified or who participate or
5735	5735	4 have participated in any of the programs described in
5736	5736	5 this Act.
5737	5737	6 (2) The Agency shall create an easily accessible,
5738	5738	7 public facing online tool using the database information
5739	5739	8 that includes, at a minimum, the following:
5740	5740	9 (A) a map of environmental justice and equity
5741	5741	10 investment eligible communities;
5742	5742	11 (B) job postings and recruiting opportunities;
5743	5743	12 (C) a means by which recruiting clean energy
5744	5744	13 companies can find and interact with current or former
5745	5745	14 participants of clean energy workforce training
5746	5746	15 programs;
5747	5747	16 (D) information on workforce training service
5748	5748	17 providers and training opportunities available to
5749	5749	18 prospective workers;
5750	5750	19 (E) renewable energy company diversity reporting;
5751	5751	20 (F) a list of equity eligible contractors with
5752	5752	21 their contact information, types of work performed,
5753	5753	22 and locations worked in;
5754	5754	23 (G) reporting on outcomes of the programs
5755	5755	24 described in the workforce programs of the Energy
5756	5756	25 Transition Act, including information such as, but not
5757	5757	26 limited to, retention rate, graduation rate, and
5758	5758
5759	5759
5760	5760
5761	5761
5762	5762
5763	5763	HB5514 - 159 - LRB103 39335 CES 69496 b
5764	5764
5765	5765
5766	5766	HB5514- 160 -LRB103 39335 CES 69496 b HB5514 - 160 - LRB103 39335 CES 69496 b
5767	5767	HB5514 - 160 - LRB103 39335 CES 69496 b
5768	5768	1 placement rates of trainees; and
5769	5769	2 (H) information about the Jobs and Environmental
5770	5770	3 Justice Grant Program, the Clean Energy Jobs and
5771	5771	4 Justice Fund, and other sources of capital.
5772	5772	5 (3) The Agency shall ensure the database is regularly
5773	5773	6 updated to ensure information is current and shall
5774	5774	7 coordinate with the Department of Commerce and Economic
5775	5775	8 Opportunity to ensure that it includes information on
5776	5776	9 individuals and entities that are or have participated in
5777	5777	10 the Clean Jobs Workforce Network Program, Clean Energy
5778	5778	11 Contractor Incubator Program, Returning Residents Clean
5779	5779	12 Jobs Training Program, or Clean Energy Primes Contractor
5780	5780	13 Accelerator Program.
5781	5781	14 (c-30) Enforcement of minimum equity standards. All
5782	5782	15 entities seeking renewable energy credits must submit an
5783	5783	16 annual report to demonstrate compliance with each of the
5784	5784	17 equity commitments required under subsection (c-10). If the
5785	5785	18 Agency concludes the entity has not met or maintained its
5786	5786	19 minimum equity standards required under the applicable
5787	5787	20 subparagraphs under subsection (c-10), the Agency shall deny
5788	5788	21 the entity's ability to participate in procurement programs in
5789	5789	22 subsection (c), including by withholding approved vendor or
5790	5790	23 designee status. The Agency may require the entity to enter
5791	5791	24 into a corrective action plan. An entity that is not
5792	5792	25 recertified for failing to meet required equity actions in
5793	5793	26 subparagraph (c-10) may reapply once they have a corrective
5794	5794
5795	5795
5796	5796
5797	5797
5798	5798
5799	5799	HB5514 - 160 - LRB103 39335 CES 69496 b
5800	5800
5801	5801
5802	5802	HB5514- 161 -LRB103 39335 CES 69496 b HB5514 - 161 - LRB103 39335 CES 69496 b
5803	5803	HB5514 - 161 - LRB103 39335 CES 69496 b
5804	5804	1 action plan and achieve compliance with the minimum equity
5805	5805	2 standards.
5806	5806	3 (d) Clean coal portfolio standard.
5807	5807	4 (1) The procurement plans shall include electricity
5808	5808	5 generated using clean coal. Each utility shall enter into
5809	5809	6 one or more sourcing agreements with the initial clean
5810	5810	7 coal facility, as provided in paragraph (3) of this
5811	5811	8 subsection (d), covering electricity generated by the
5812	5812	9 initial clean coal facility representing at least 5% of
5813	5813	10 each utility's total supply to serve the load of eligible
5814	5814	11 retail customers in 2015 and each year thereafter, as
5815	5815	12 described in paragraph (3) of this subsection (d), subject
5816	5816	13 to the limits specified in paragraph (2) of this
5817	5817	14 subsection (d). It is the goal of the State that by January
5818	5818	15 1, 2025, 25% of the electricity used in the State shall be
5819	5819	16 generated by cost-effective clean coal facilities. For
5820	5820	17 purposes of this subsection (d), "cost-effective" means
5821	5821	18 that the expenditures pursuant to such sourcing agreements
5822	5822	19 do not cause the limit stated in paragraph (2) of this
5823	5823	20 subsection (d) to be exceeded and do not exceed cost-based
5824	5824	21 benchmarks, which shall be developed to assess all
5825	5825	22 expenditures pursuant to such sourcing agreements covering
5826	5826	23 electricity generated by clean coal facilities, other than
5827	5827	24 the initial clean coal facility, by the procurement
5828	5828	25 administrator, in consultation with the Commission staff,
5829	5829	26 Agency staff, and the procurement monitor and shall be
5830	5830
5831	5831
5832	5832
5833	5833
5834	5834
5835	5835	HB5514 - 161 - LRB103 39335 CES 69496 b
5836	5836
5837	5837
5838	5838	HB5514- 162 -LRB103 39335 CES 69496 b HB5514 - 162 - LRB103 39335 CES 69496 b
5839	5839	HB5514 - 162 - LRB103 39335 CES 69496 b
5840	5840	1 subject to Commission review and approval.
5841	5841	2 A utility party to a sourcing agreement shall
5842	5842	3 immediately retire any emission credits that it receives
5843	5843	4 in connection with the electricity covered by such
5844	5844	5 agreement.
5845	5845	6 Utilities shall maintain adequate records documenting
5846	5846	7 the purchases under the sourcing agreement to comply with
5847	5847	8 this subsection (d) and shall file an accounting with the
5848	5848	9 load forecast that must be filed with the Agency by July 15
5849	5849	10 of each year, in accordance with subsection (d) of Section
5850	5850	11 16-111.5 of the Public Utilities Act.
5851	5851	12 A utility shall be deemed to have complied with the
5852	5852	13 clean coal portfolio standard specified in this subsection
5853	5853	14 (d) if the utility enters into a sourcing agreement as
5854	5854	15 required by this subsection (d).
5855	5855	16 (2) For purposes of this subsection (d), the required
5856	5856	17 execution of sourcing agreements with the initial clean
5857	5857	18 coal facility for a particular year shall be measured as a
5858	5858	19 percentage of the actual amount of electricity
5859	5859	20 (megawatt-hours) supplied by the electric utility to
5860	5860	21 eligible retail customers in the planning year ending
5861	5861	22 immediately prior to the agreement's execution. For
5862	5862	23 purposes of this subsection (d), the amount paid per
5863	5863	24 kilowatthour means the total amount paid for electric
5864	5864	25 service expressed on a per kilowatthour basis. For
5865	5865	26 purposes of this subsection (d), the total amount paid for
5866	5866
5867	5867
5868	5868
5869	5869
5870	5870
5871	5871	HB5514 - 162 - LRB103 39335 CES 69496 b
5872	5872
5873	5873
5874	5874	HB5514- 163 -LRB103 39335 CES 69496 b HB5514 - 163 - LRB103 39335 CES 69496 b
5875	5875	HB5514 - 163 - LRB103 39335 CES 69496 b
5876	5876	1 electric service includes without limitation amounts paid
5877	5877	2 for supply, transmission, distribution, surcharges and
5878	5878	3 add-on taxes.
5879	5879	4 Notwithstanding the requirements of this subsection
5880	5880	5 (d), the total amount paid under sourcing agreements with
5881	5881	6 clean coal facilities pursuant to the procurement plan for
5882	5882	7 any given year shall be reduced by an amount necessary to
5883	5883	8 limit the annual estimated average net increase due to the
5884	5884	9 costs of these resources included in the amounts paid by
5885	5885	10 eligible retail customers in connection with electric
5886	5886	11 service to:
5887	5887	12 (A) in 2010, no more than 0.5% of the amount paid
5888	5888	13 per kilowatthour by those customers during the year
5889	5889	14 ending May 31, 2009;
5890	5890	15 (B) in 2011, the greater of an additional 0.5% of
5891	5891	16 the amount paid per kilowatthour by those customers
5892	5892	17 during the year ending May 31, 2010 or 1% of the amount
5893	5893	18 paid per kilowatthour by those customers during the
5894	5894	19 year ending May 31, 2009;
5895	5895	20 (C) in 2012, the greater of an additional 0.5% of
5896	5896	21 the amount paid per kilowatthour by those customers
5897	5897	22 during the year ending May 31, 2011 or 1.5% of the
5898	5898	23 amount paid per kilowatthour by those customers during
5899	5899	24 the year ending May 31, 2009;
5900	5900	25 (D) in 2013, the greater of an additional 0.5% of
5901	5901	26 the amount paid per kilowatthour by those customers
5902	5902
5903	5903
5904	5904
5905	5905
5906	5906
5907	5907	HB5514 - 163 - LRB103 39335 CES 69496 b
5908	5908
5909	5909
5910	5910	HB5514- 164 -LRB103 39335 CES 69496 b HB5514 - 164 - LRB103 39335 CES 69496 b
5911	5911	HB5514 - 164 - LRB103 39335 CES 69496 b
5912	5912	1 during the year ending May 31, 2012 or 2% of the amount
5913	5913	2 paid per kilowatthour by those customers during the
5914	5914	3 year ending May 31, 2009; and
5915	5915	4 (E) thereafter, the total amount paid under
5916	5916	5 sourcing agreements with clean coal facilities
5917	5917	6 pursuant to the procurement plan for any single year
5918	5918	7 shall be reduced by an amount necessary to limit the
5919	5919	8 estimated average net increase due to the cost of
5920	5920	9 these resources included in the amounts paid by
5921	5921	10 eligible retail customers in connection with electric
5922	5922	11 service to no more than the greater of (i) 2.015% of
5923	5923	12 the amount paid per kilowatthour by those customers
5924	5924	13 during the year ending May 31, 2009 or (ii) the
5925	5925	14 incremental amount per kilowatthour paid for these
5926	5926	15 resources in 2013. These requirements may be altered
5927	5927	16 only as provided by statute.
5928	5928	17 No later than June 30, 2015, the Commission shall
5929	5929	18 review the limitation on the total amount paid under
5930	5930	19 sourcing agreements, if any, with clean coal facilities
5931	5931	20 pursuant to this subsection (d) and report to the General
5932	5932	21 Assembly its findings as to whether that limitation unduly
5933	5933	22 constrains the amount of electricity generated by
5934	5934	23 cost-effective clean coal facilities that is covered by
5935	5935	24 sourcing agreements.
5936	5936	25 (3) Initial clean coal facility. In order to promote
5937	5937	26 development of clean coal facilities in Illinois, each
5938	5938
5939	5939
5940	5940
5941	5941
5942	5942
5943	5943	HB5514 - 164 - LRB103 39335 CES 69496 b
5944	5944
5945	5945
5946	5946	HB5514- 165 -LRB103 39335 CES 69496 b HB5514 - 165 - LRB103 39335 CES 69496 b
5947	5947	HB5514 - 165 - LRB103 39335 CES 69496 b
5948	5948	1 electric utility subject to this Section shall execute a
5949	5949	2 sourcing agreement to source electricity from a proposed
5950	5950	3 clean coal facility in Illinois (the "initial clean coal
5951	5951	4 facility") that will have a nameplate capacity of at least
5952	5952	5 500 MW when commercial operation commences, that has a
5953	5953	6 final Clean Air Act permit on June 1, 2009 (the effective
5954	5954	7 date of Public Act 95-1027), and that will meet the
5955	5955	8 definition of clean coal facility in Section 1-10 of this
5956	5956	9 Act when commercial operation commences. The sourcing
5957	5957	10 agreements with this initial clean coal facility shall be
5958	5958	11 subject to both approval of the initial clean coal
5959	5959	12 facility by the General Assembly and satisfaction of the
5960	5960	13 requirements of paragraph (4) of this subsection (d) and
5961	5961	14 shall be executed within 90 days after any such approval
5962	5962	15 by the General Assembly. The Agency and the Commission
5963	5963	16 shall have authority to inspect all books and records
5964	5964	17 associated with the initial clean coal facility during the
5965	5965	18 term of such a sourcing agreement. A utility's sourcing
5966	5966	19 agreement for electricity produced by the initial clean
5967	5967	20 coal facility shall include:
5968	5968	21 (A) a formula contractual price (the "contract
5969	5969	22 price") approved pursuant to paragraph (4) of this
5970	5970	23 subsection (d), which shall:
5971	5971	24 (i) be determined using a cost of service
5972	5972	25 methodology employing either a level or deferred
5973	5973	26 capital recovery component, based on a capital
5974	5974
5975	5975
5976	5976
5977	5977
5978	5978
5979	5979	HB5514 - 165 - LRB103 39335 CES 69496 b
5980	5980
5981	5981
5982	5982	HB5514- 166 -LRB103 39335 CES 69496 b HB5514 - 166 - LRB103 39335 CES 69496 b
5983	5983	HB5514 - 166 - LRB103 39335 CES 69496 b
5984	5984	1 structure consisting of 45% equity and 55% debt,
5985	5985	2 and a return on equity as may be approved by the
5986	5986	3 Federal Energy Regulatory Commission, which in any
5987	5987	4 case may not exceed the lower of 11.5% or the rate
5988	5988	5 of return approved by the General Assembly
5989	5989	6 pursuant to paragraph (4) of this subsection (d);
5990	5990	7 and
5991	5991	8 (ii) provide that all miscellaneous net
5992	5992	9 revenue, including but not limited to net revenue
5993	5993	10 from the sale of emission allowances, if any,
5994	5994	11 substitute natural gas, if any, grants or other
5995	5995	12 support provided by the State of Illinois or the
5996	5996	13 United States Government, firm transmission
5997	5997	14 rights, if any, by-products produced by the
5998	5998	15 facility, energy or capacity derived from the
5999	5999	16 facility and not covered by a sourcing agreement
6000	6000	17 pursuant to paragraph (3) of this subsection (d)
6001	6001	18 or item (5) of subsection (d) of Section 16-115 of
6002	6002	19 the Public Utilities Act, whether generated from
6003	6003	20 the synthesis gas derived from coal, from SNG, or
6004	6004	21 from natural gas, shall be credited against the
6005	6005	22 revenue requirement for this initial clean coal
6006	6006	23 facility;
6007	6007	24 (B) power purchase provisions, which shall:
6008	6008	25 (i) provide that the utility party to such
6009	6009	26 sourcing agreement shall pay the contract price
6010	6010
6011	6011
6012	6012
6013	6013
6014	6014
6015	6015	HB5514 - 166 - LRB103 39335 CES 69496 b
6016	6016
6017	6017
6018	6018	HB5514- 167 -LRB103 39335 CES 69496 b HB5514 - 167 - LRB103 39335 CES 69496 b
6019	6019	HB5514 - 167 - LRB103 39335 CES 69496 b
6020	6020	1 for electricity delivered under such sourcing
6021	6021	2 agreement;
6022	6022	3 (ii) require delivery of electricity to the
6023	6023	4 regional transmission organization market of the
6024	6024	5 utility that is party to such sourcing agreement;
6025	6025	6 (iii) require the utility party to such
6026	6026	7 sourcing agreement to buy from the initial clean
6027	6027	8 coal facility in each hour an amount of energy
6028	6028	9 equal to all clean coal energy made available from
6029	6029	10 the initial clean coal facility during such hour
6030	6030	11 times a fraction, the numerator of which is such
6031	6031	12 utility's retail market sales of electricity
6032	6032	13 (expressed in kilowatthours sold) in the State
6033	6033	14 during the prior calendar month and the
6034	6034	15 denominator of which is the total retail market
6035	6035	16 sales of electricity (expressed in kilowatthours
6036	6036	17 sold) in the State by utilities during such prior
6037	6037	18 month and the sales of electricity (expressed in
6038	6038	19 kilowatthours sold) in the State by alternative
6039	6039	20 retail electric suppliers during such prior month
6040	6040	21 that are subject to the requirements of this
6041	6041	22 subsection (d) and paragraph (5) of subsection (d)
6042	6042	23 of Section 16-115 of the Public Utilities Act,
6043	6043	24 provided that the amount purchased by the utility
6044	6044	25 in any year will be limited by paragraph (2) of
6045	6045	26 this subsection (d); and
6046	6046
6047	6047
6048	6048
6049	6049
6050	6050
6051	6051	HB5514 - 167 - LRB103 39335 CES 69496 b
6052	6052
6053	6053
6054	6054	HB5514- 168 -LRB103 39335 CES 69496 b HB5514 - 168 - LRB103 39335 CES 69496 b
6055	6055	HB5514 - 168 - LRB103 39335 CES 69496 b
6056	6056	1 (iv) be considered pre-existing contracts in
6057	6057	2 such utility's procurement plans for eligible
6058	6058	3 retail customers;
6059	6059	4 (C) contract for differences provisions, which
6060	6060	5 shall:
6061	6061	6 (i) require the utility party to such sourcing
6062	6062	7 agreement to contract with the initial clean coal
6063	6063	8 facility in each hour with respect to an amount of
6064	6064	9 energy equal to all clean coal energy made
6065	6065	10 available from the initial clean coal facility
6066	6066	11 during such hour times a fraction, the numerator
6067	6067	12 of which is such utility's retail market sales of
6068	6068	13 electricity (expressed in kilowatthours sold) in
6069	6069	14 the utility's service territory in the State
6070	6070	15 during the prior calendar month and the
6071	6071	16 denominator of which is the total retail market
6072	6072	17 sales of electricity (expressed in kilowatthours
6073	6073	18 sold) in the State by utilities during such prior
6074	6074	19 month and the sales of electricity (expressed in
6075	6075	20 kilowatthours sold) in the State by alternative
6076	6076	21 retail electric suppliers during such prior month
6077	6077	22 that are subject to the requirements of this
6078	6078	23 subsection (d) and paragraph (5) of subsection (d)
6079	6079	24 of Section 16-115 of the Public Utilities Act,
6080	6080	25 provided that the amount paid by the utility in
6081	6081	26 any year will be limited by paragraph (2) of this
6082	6082
6083	6083
6084	6084
6085	6085
6086	6086
6087	6087	HB5514 - 168 - LRB103 39335 CES 69496 b
6088	6088
6089	6089
6090	6090	HB5514- 169 -LRB103 39335 CES 69496 b HB5514 - 169 - LRB103 39335 CES 69496 b
6091	6091	HB5514 - 169 - LRB103 39335 CES 69496 b
6092	6092	1 subsection (d);
6093	6093	2 (ii) provide that the utility's payment
6094	6094	3 obligation in respect of the quantity of
6095	6095	4 electricity determined pursuant to the preceding
6096	6096	5 clause (i) shall be limited to an amount equal to
6097	6097	6 (1) the difference between the contract price
6098	6098	7 determined pursuant to subparagraph (A) of
6099	6099	8 paragraph (3) of this subsection (d) and the
6100	6100	9 day-ahead price for electricity delivered to the
6101	6101	10 regional transmission organization market of the
6102	6102	11 utility that is party to such sourcing agreement
6103	6103	12 (or any successor delivery point at which such
6104	6104	13 utility's supply obligations are financially
6105	6105	14 settled on an hourly basis) (the "reference
6106	6106	15 price") on the day preceding the day on which the
6107	6107	16 electricity is delivered to the initial clean coal
6108	6108	17 facility busbar, multiplied by (2) the quantity of
6109	6109	18 electricity determined pursuant to the preceding
6110	6110	19 clause (i); and
6111	6111	20 (iii) not require the utility to take physical
6112	6112	21 delivery of the electricity produced by the
6113	6113	22 facility;
6114	6114	23 (D) general provisions, which shall:
6115	6115	24 (i) specify a term of no more than 30 years,
6116	6116	25 commencing on the commercial operation date of the
6117	6117	26 facility;
6118	6118
6119	6119
6120	6120
6121	6121
6122	6122
6123	6123	HB5514 - 169 - LRB103 39335 CES 69496 b
6124	6124
6125	6125
6126	6126	HB5514- 170 -LRB103 39335 CES 69496 b HB5514 - 170 - LRB103 39335 CES 69496 b
6127	6127	HB5514 - 170 - LRB103 39335 CES 69496 b
6128	6128	1 (ii) provide that utilities shall maintain
6129	6129	2 adequate records documenting purchases under the
6130	6130	3 sourcing agreements entered into to comply with
6131	6131	4 this subsection (d) and shall file an accounting
6132	6132	5 with the load forecast that must be filed with the
6133	6133	6 Agency by July 15 of each year, in accordance with
6134	6134	7 subsection (d) of Section 16-111.5 of the Public
6135	6135	8 Utilities Act;
6136	6136	9 (iii) provide that all costs associated with
6137	6137	10 the initial clean coal facility will be
6138	6138	11 periodically reported to the Federal Energy
6139	6139	12 Regulatory Commission and to purchasers in
6140	6140	13 accordance with applicable laws governing
6141	6141	14 cost-based wholesale power contracts;
6142	6142	15 (iv) permit the Illinois Power Agency to
6143	6143	16 assume ownership of the initial clean coal
6144	6144	17 facility, without monetary consideration and
6145	6145	18 otherwise on reasonable terms acceptable to the
6146	6146	19 Agency, if the Agency so requests no less than 3
6147	6147	20 years prior to the end of the stated contract
6148	6148	21 term;
6149	6149	22 (v) require the owner of the initial clean
6150	6150	23 coal facility to provide documentation to the
6151	6151	24 Commission each year, starting in the facility's
6152	6152	25 first year of commercial operation, accurately
6153	6153	26 reporting the quantity of carbon emissions from
6154	6154
6155	6155
6156	6156
6157	6157
6158	6158
6159	6159	HB5514 - 170 - LRB103 39335 CES 69496 b
6160	6160
6161	6161
6162	6162	HB5514- 171 -LRB103 39335 CES 69496 b HB5514 - 171 - LRB103 39335 CES 69496 b
6163	6163	HB5514 - 171 - LRB103 39335 CES 69496 b
6164	6164	1 the facility that have been captured and
6165	6165	2 sequestered and report any quantities of carbon
6166	6166	3 released from the site or sites at which carbon
6167	6167	4 emissions were sequestered in prior years, based
6168	6168	5 on continuous monitoring of such sites. If, in any
6169	6169	6 year after the first year of commercial operation,
6170	6170	7 the owner of the facility fails to demonstrate
6171	6171	8 that the initial clean coal facility captured and
6172	6172	9 sequestered at least 50% of the total carbon
6173	6173	10 emissions that the facility would otherwise emit
6174	6174	11 or that sequestration of emissions from prior
6175	6175	12 years has failed, resulting in the release of
6176	6176	13 carbon dioxide into the atmosphere, the owner of
6177	6177	14 the facility must offset excess emissions. Any
6178	6178	15 such carbon offsets must be permanent, additional,
6179	6179	16 verifiable, real, located within the State of
6180	6180	17 Illinois, and legally and practicably enforceable.
6181	6181	18 The cost of such offsets for the facility that are
6182	6182	19 not recoverable shall not exceed $15 million in
6183	6183	20 any given year. No costs of any such purchases of
6184	6184	21 carbon offsets may be recovered from a utility or
6185	6185	22 its customers. All carbon offsets purchased for
6186	6186	23 this purpose and any carbon emission credits
6187	6187	24 associated with sequestration of carbon from the
6188	6188	25 facility must be permanently retired. The initial
6189	6189	26 clean coal facility shall not forfeit its
6190	6190
6191	6191
6192	6192
6193	6193
6194	6194
6195	6195	HB5514 - 171 - LRB103 39335 CES 69496 b
6196	6196
6197	6197
6198	6198	HB5514- 172 -LRB103 39335 CES 69496 b HB5514 - 172 - LRB103 39335 CES 69496 b
6199	6199	HB5514 - 172 - LRB103 39335 CES 69496 b
6200	6200	1 designation as a clean coal facility if the
6201	6201	2 facility fails to fully comply with the applicable
6202	6202	3 carbon sequestration requirements in any given
6203	6203	4 year, provided the requisite offsets are
6204	6204	5 purchased. However, the Attorney General, on
6205	6205	6 behalf of the People of the State of Illinois, may
6206	6206	7 specifically enforce the facility's sequestration
6207	6207	8 requirement and the other terms of this contract
6208	6208	9 provision. Compliance with the sequestration
6209	6209	10 requirements and offset purchase requirements
6210	6210	11 specified in paragraph (3) of this subsection (d)
6211	6211	12 shall be reviewed annually by an independent
6212	6212	13 expert retained by the owner of the initial clean
6213	6213	14 coal facility, with the advance written approval
6214	6214	15 of the Attorney General. The Commission may, in
6215	6215	16 the course of the review specified in item (vii),
6216	6216	17 reduce the allowable return on equity for the
6217	6217	18 facility if the facility willfully fails to comply
6218	6218	19 with the carbon capture and sequestration
6219	6219	20 requirements set forth in this item (v);
6220	6220	21 (vi) include limits on, and accordingly
6221	6221	22 provide for modification of, the amount the
6222	6222	23 utility is required to source under the sourcing
6223	6223	24 agreement consistent with paragraph (2) of this
6224	6224	25 subsection (d);
6225	6225	26 (vii) require Commission review: (1) to
6226	6226
6227	6227
6228	6228
6229	6229
6230	6230
6231	6231	HB5514 - 172 - LRB103 39335 CES 69496 b
6232	6232
6233	6233
6234	6234	HB5514- 173 -LRB103 39335 CES 69496 b HB5514 - 173 - LRB103 39335 CES 69496 b
6235	6235	HB5514 - 173 - LRB103 39335 CES 69496 b
6236	6236	1 determine the justness, reasonableness, and
6237	6237	2 prudence of the inputs to the formula referenced
6238	6238	3 in subparagraphs (A)(i) through (A)(iii) of
6239	6239	4 paragraph (3) of this subsection (d), prior to an
6240	6240	5 adjustment in those inputs including, without
6241	6241	6 limitation, the capital structure and return on
6242	6242	7 equity, fuel costs, and other operations and
6243	6243	8 maintenance costs and (2) to approve the costs to
6244	6244	9 be passed through to customers under the sourcing
6245	6245	10 agreement by which the utility satisfies its
6246	6246	11 statutory obligations. Commission review shall
6247	6247	12 occur no less than every 3 years, regardless of
6248	6248	13 whether any adjustments have been proposed, and
6249	6249	14 shall be completed within 9 months;
6250	6250	15 (viii) limit the utility's obligation to such
6251	6251	16 amount as the utility is allowed to recover
6252	6252	17 through tariffs filed with the Commission,
6253	6253	18 provided that neither the clean coal facility nor
6254	6254	19 the utility waives any right to assert federal
6255	6255	20 pre-emption or any other argument in response to a
6256	6256	21 purported disallowance of recovery costs;
6257	6257	22 (ix) limit the utility's or alternative retail
6258	6258	23 electric supplier's obligation to incur any
6259	6259	24 liability until such time as the facility is in
6260	6260	25 commercial operation and generating power and
6261	6261	26 energy and such power and energy is being
6262	6262
6263	6263
6264	6264
6265	6265
6266	6266
6267	6267	HB5514 - 173 - LRB103 39335 CES 69496 b
6268	6268
6269	6269
6270	6270	HB5514- 174 -LRB103 39335 CES 69496 b HB5514 - 174 - LRB103 39335 CES 69496 b
6271	6271	HB5514 - 174 - LRB103 39335 CES 69496 b
6272	6272	1 delivered to the facility busbar;
6273	6273	2 (x) provide that the owner or owners of the
6274	6274	3 initial clean coal facility, which is the
6275	6275	4 counterparty to such sourcing agreement, shall
6276	6276	5 have the right from time to time to elect whether
6277	6277	6 the obligations of the utility party thereto shall
6278	6278	7 be governed by the power purchase provisions or
6279	6279	8 the contract for differences provisions;
6280	6280	9 (xi) append documentation showing that the
6281	6281	10 formula rate and contract, insofar as they relate
6282	6282	11 to the power purchase provisions, have been
6283	6283	12 approved by the Federal Energy Regulatory
6284	6284	13 Commission pursuant to Section 205 of the Federal
6285	6285	14 Power Act;
6286	6286	15 (xii) provide that any changes to the terms of
6287	6287	16 the contract, insofar as such changes relate to
6288	6288	17 the power purchase provisions, are subject to
6289	6289	18 review under the public interest standard applied
6290	6290	19 by the Federal Energy Regulatory Commission
6291	6291	20 pursuant to Sections 205 and 206 of the Federal
6292	6292	21 Power Act; and
6293	6293	22 (xiii) conform with customary lender
6294	6294	23 requirements in power purchase agreements used as
6295	6295	24 the basis for financing non-utility generators.
6296	6296	25 (4) Effective date of sourcing agreements with the
6297	6297	26 initial clean coal facility. Any proposed sourcing
6298	6298
6299	6299
6300	6300
6301	6301
6302	6302
6303	6303	HB5514 - 174 - LRB103 39335 CES 69496 b
6304	6304
6305	6305
6306	6306	HB5514- 175 -LRB103 39335 CES 69496 b HB5514 - 175 - LRB103 39335 CES 69496 b
6307	6307	HB5514 - 175 - LRB103 39335 CES 69496 b
6308	6308	1 agreement with the initial clean coal facility shall not
6309	6309	2 become effective unless the following reports are prepared
6310	6310	3 and submitted and authorizations and approvals obtained:
6311	6311	4 (i) Facility cost report. The owner of the initial
6312	6312	5 clean coal facility shall submit to the Commission,
6313	6313	6 the Agency, and the General Assembly a front-end
6314	6314	7 engineering and design study, a facility cost report,
6315	6315	8 method of financing (including but not limited to
6316	6316	9 structure and associated costs), and an operating and
6317	6317	10 maintenance cost quote for the facility (collectively
6318	6318	11 "facility cost report"), which shall be prepared in
6319	6319	12 accordance with the requirements of this paragraph (4)
6320	6320	13 of subsection (d) of this Section, and shall provide
6321	6321	14 the Commission and the Agency access to the work
6322	6322	15 papers, relied upon documents, and any other backup
6323	6323	16 documentation related to the facility cost report.
6324	6324	17 (ii) Commission report. Within 6 months following
6325	6325	18 receipt of the facility cost report, the Commission,
6326	6326	19 in consultation with the Agency, shall submit a report
6327	6327	20 to the General Assembly setting forth its analysis of
6328	6328	21 the facility cost report. Such report shall include,
6329	6329	22 but not be limited to, a comparison of the costs
6330	6330	23 associated with electricity generated by the initial
6331	6331	24 clean coal facility to the costs associated with
6332	6332	25 electricity generated by other types of generation
6333	6333	26 facilities, an analysis of the rate impacts on
6334	6334
6335	6335
6336	6336
6337	6337
6338	6338
6339	6339	HB5514 - 175 - LRB103 39335 CES 69496 b
6340	6340
6341	6341
6342	6342	HB5514- 176 -LRB103 39335 CES 69496 b HB5514 - 176 - LRB103 39335 CES 69496 b
6343	6343	HB5514 - 176 - LRB103 39335 CES 69496 b
6344	6344	1 residential and small business customers over the life
6345	6345	2 of the sourcing agreements, and an analysis of the
6346	6346	3 likelihood that the initial clean coal facility will
6347	6347	4 commence commercial operation by and be delivering
6348	6348	5 power to the facility's busbar by 2016. To assist in
6349	6349	6 the preparation of its report, the Commission, in
6350	6350	7 consultation with the Agency, may hire one or more
6351	6351	8 experts or consultants, the costs of which shall be
6352	6352	9 paid for by the owner of the initial clean coal
6353	6353	10 facility. The Commission and Agency may begin the
6354	6354	11 process of selecting such experts or consultants prior
6355	6355	12 to receipt of the facility cost report.
6356	6356	13 (iii) General Assembly approval. The proposed
6357	6357	14 sourcing agreements shall not take effect unless,
6358	6358	15 based on the facility cost report and the Commission's
6359	6359	16 report, the General Assembly enacts authorizing
6360	6360	17 legislation approving (A) the projected price, stated
6361	6361	18 in cents per kilowatthour, to be charged for
6362	6362	19 electricity generated by the initial clean coal
6363	6363	20 facility, (B) the projected impact on residential and
6364	6364	21 small business customers' bills over the life of the
6365	6365	22 sourcing agreements, and (C) the maximum allowable
6366	6366	23 return on equity for the project; and
6367	6367	24 (iv) Commission review. If the General Assembly
6368	6368	25 enacts authorizing legislation pursuant to
6369	6369	26 subparagraph (iii) approving a sourcing agreement, the
6370	6370
6371	6371
6372	6372
6373	6373
6374	6374
6375	6375	HB5514 - 176 - LRB103 39335 CES 69496 b
6376	6376
6377	6377
6378	6378	HB5514- 177 -LRB103 39335 CES 69496 b HB5514 - 177 - LRB103 39335 CES 69496 b
6379	6379	HB5514 - 177 - LRB103 39335 CES 69496 b
6380	6380	1 Commission shall, within 90 days of such enactment,
6381	6381	2 complete a review of such sourcing agreement. During
6382	6382	3 such time period, the Commission shall implement any
6383	6383	4 directive of the General Assembly, resolve any
6384	6384	5 disputes between the parties to the sourcing agreement
6385	6385	6 concerning the terms of such agreement, approve the
6386	6386	7 form of such agreement, and issue an order finding
6387	6387	8 that the sourcing agreement is prudent and reasonable.
6388	6388	9 The facility cost report shall be prepared as follows:
6389	6389	10 (A) The facility cost report shall be prepared by
6390	6390	11 duly licensed engineering and construction firms
6391	6391	12 detailing the estimated capital costs payable to one
6392	6392	13 or more contractors or suppliers for the engineering,
6393	6393	14 procurement and construction of the components
6394	6394	15 comprising the initial clean coal facility and the
6395	6395	16 estimated costs of operation and maintenance of the
6396	6396	17 facility. The facility cost report shall include:
6397	6397	18 (i) an estimate of the capital cost of the
6398	6398	19 core plant based on one or more front end
6399	6399	20 engineering and design studies for the
6400	6400	21 gasification island and related facilities. The
6401	6401	22 core plant shall include all civil, structural,
6402	6402	23 mechanical, electrical, control, and safety
6403	6403	24 systems.
6404	6404	25 (ii) an estimate of the capital cost of the
6405	6405	26 balance of the plant, including any capital costs
6406	6406
6407	6407
6408	6408
6409	6409
6410	6410
6411	6411	HB5514 - 177 - LRB103 39335 CES 69496 b
6412	6412
6413	6413
6414	6414	HB5514- 178 -LRB103 39335 CES 69496 b HB5514 - 178 - LRB103 39335 CES 69496 b
6415	6415	HB5514 - 178 - LRB103 39335 CES 69496 b
6416	6416	1 associated with sequestration of carbon dioxide
6417	6417	2 emissions and all interconnects and interfaces
6418	6418	3 required to operate the facility, such as
6419	6419	4 transmission of electricity, construction or
6420	6420	5 backfeed power supply, pipelines to transport
6421	6421	6 substitute natural gas or carbon dioxide, potable
6422	6422	7 water supply, natural gas supply, water supply,
6423	6423	8 water discharge, landfill, access roads, and coal
6424	6424	9 delivery.
6425	6425	10 The quoted construction costs shall be expressed
6426	6426	11 in nominal dollars as of the date that the quote is
6427	6427	12 prepared and shall include capitalized financing costs
6428	6428	13 during construction, taxes, insurance, and other
6429	6429	14 owner's costs, and an assumed escalation in materials
6430	6430	15 and labor beyond the date as of which the construction
6431	6431	16 cost quote is expressed.
6432	6432	17 (B) The front end engineering and design study for
6433	6433	18 the gasification island and the cost study for the
6434	6434	19 balance of plant shall include sufficient design work
6435	6435	20 to permit quantification of major categories of
6436	6436	21 materials, commodities and labor hours, and receipt of
6437	6437	22 quotes from vendors of major equipment required to
6438	6438	23 construct and operate the clean coal facility.
6439	6439	24 (C) The facility cost report shall also include an
6440	6440	25 operating and maintenance cost quote that will provide
6441	6441	26 the estimated cost of delivered fuel, personnel,
6442	6442
6443	6443
6444	6444
6445	6445
6446	6446
6447	6447	HB5514 - 178 - LRB103 39335 CES 69496 b
6448	6448
6449	6449
6450	6450	HB5514- 179 -LRB103 39335 CES 69496 b HB5514 - 179 - LRB103 39335 CES 69496 b
6451	6451	HB5514 - 179 - LRB103 39335 CES 69496 b
6452	6452	1 maintenance contracts, chemicals, catalysts,
6453	6453	2 consumables, spares, and other fixed and variable
6454	6454	3 operations and maintenance costs. The delivered fuel
6455	6455	4 cost estimate will be provided by a recognized third
6456	6456	5 party expert or experts in the fuel and transportation
6457	6457	6 industries. The balance of the operating and
6458	6458	7 maintenance cost quote, excluding delivered fuel
6459	6459	8 costs, will be developed based on the inputs provided
6460	6460	9 by duly licensed engineering and construction firms
6461	6461	10 performing the construction cost quote, potential
6462	6462	11 vendors under long-term service agreements and plant
6463	6463	12 operating agreements, or recognized third party plant
6464	6464	13 operator or operators.
6465	6465	14 The operating and maintenance cost quote
6466	6466	15 (including the cost of the front end engineering and
6467	6467	16 design study) shall be expressed in nominal dollars as
6468	6468	17 of the date that the quote is prepared and shall
6469	6469	18 include taxes, insurance, and other owner's costs, and
6470	6470	19 an assumed escalation in materials and labor beyond
6471	6471	20 the date as of which the operating and maintenance
6472	6472	21 cost quote is expressed.
6473	6473	22 (D) The facility cost report shall also include an
6474	6474	23 analysis of the initial clean coal facility's ability
6475	6475	24 to deliver power and energy into the applicable
6476	6476	25 regional transmission organization markets and an
6477	6477	26 analysis of the expected capacity factor for the
6478	6478
6479	6479
6480	6480
6481	6481
6482	6482
6483	6483	HB5514 - 179 - LRB103 39335 CES 69496 b
6484	6484
6485	6485
6486	6486	HB5514- 180 -LRB103 39335 CES 69496 b HB5514 - 180 - LRB103 39335 CES 69496 b
6487	6487	HB5514 - 180 - LRB103 39335 CES 69496 b
6488	6488	1 initial clean coal facility.
6489	6489	2 (E) Amounts paid to third parties unrelated to the
6490	6490	3 owner or owners of the initial clean coal facility to
6491	6491	4 prepare the core plant construction cost quote,
6492	6492	5 including the front end engineering and design study,
6493	6493	6 and the operating and maintenance cost quote will be
6494	6494	7 reimbursed through Coal Development Bonds.
6495	6495	8 (5) Re-powering and retrofitting coal-fired power
6496	6496	9 plants previously owned by Illinois utilities to qualify
6497	6497	10 as clean coal facilities. During the 2009 procurement
6498	6498	11 planning process and thereafter, the Agency and the
6499	6499	12 Commission shall consider sourcing agreements covering
6500	6500	13 electricity generated by power plants that were previously
6501	6501	14 owned by Illinois utilities and that have been or will be
6502	6502	15 converted into clean coal facilities, as defined by
6503	6503	16 Section 1-10 of this Act. Pursuant to such procurement
6504	6504	17 planning process, the owners of such facilities may
6505	6505	18 propose to the Agency sourcing agreements with utilities
6506	6506	19 and alternative retail electric suppliers required to
6507	6507	20 comply with subsection (d) of this Section and item (5) of
6508	6508	21 subsection (d) of Section 16-115 of the Public Utilities
6509	6509	22 Act, covering electricity generated by such facilities. In
6510	6510	23 the case of sourcing agreements that are power purchase
6511	6511	24 agreements, the contract price for electricity sales shall
6512	6512	25 be established on a cost of service basis. In the case of
6513	6513	26 sourcing agreements that are contracts for differences,
6514	6514
6515	6515
6516	6516
6517	6517
6518	6518
6519	6519	HB5514 - 180 - LRB103 39335 CES 69496 b
6520	6520
6521	6521
6522	6522	HB5514- 181 -LRB103 39335 CES 69496 b HB5514 - 181 - LRB103 39335 CES 69496 b
6523	6523	HB5514 - 181 - LRB103 39335 CES 69496 b
6524	6524	1 the contract price from which the reference price is
6525	6525	2 subtracted shall be established on a cost of service
6526	6526	3 basis. The Agency and the Commission may approve any such
6527	6527	4 utility sourcing agreements that do not exceed cost-based
6528	6528	5 benchmarks developed by the procurement administrator, in
6529	6529	6 consultation with the Commission staff, Agency staff and
6530	6530	7 the procurement monitor, subject to Commission review and
6531	6531	8 approval. The Commission shall have authority to inspect
6532	6532	9 all books and records associated with these clean coal
6533	6533	10 facilities during the term of any such contract.
6534	6534	11 (6) Costs incurred under this subsection (d) or
6535	6535	12 pursuant to a contract entered into under this subsection
6536	6536	13 (d) shall be deemed prudently incurred and reasonable in
6537	6537	14 amount and the electric utility shall be entitled to full
6538	6538	15 cost recovery pursuant to the tariffs filed with the
6539	6539	16 Commission.
6540	6540	17 (d-5) Zero emission standard.
6541	6541	18 (1) Beginning with the delivery year commencing on
6542	6542	19 June 1, 2017, the Agency shall, for electric utilities
6543	6543	20 that serve at least 100,000 retail customers in this
6544	6544	21 State, procure contracts with zero emission facilities
6545	6545	22 that are reasonably capable of generating cost-effective
6546	6546	23 zero emission credits in an amount approximately equal to
6547	6547	24 16% of the actual amount of electricity delivered by each
6548	6548	25 electric utility to retail customers in the State during
6549	6549	26 calendar year 2014. For an electric utility serving fewer
6550	6550
6551	6551
6552	6552
6553	6553
6554	6554
6555	6555	HB5514 - 181 - LRB103 39335 CES 69496 b
6556	6556
6557	6557
6558	6558	HB5514- 182 -LRB103 39335 CES 69496 b HB5514 - 182 - LRB103 39335 CES 69496 b
6559	6559	HB5514 - 182 - LRB103 39335 CES 69496 b
6560	6560	1 than 100,000 retail customers in this State that
6561	6561	2 requested, under Section 16-111.5 of the Public Utilities
6562	6562	3 Act, that the Agency procure power and energy for all or a
6563	6563	4 portion of the utility's Illinois load for the delivery
6564	6564	5 year commencing June 1, 2016, the Agency shall procure
6565	6565	6 contracts with zero emission facilities that are
6566	6566	7 reasonably capable of generating cost-effective zero
6567	6567	8 emission credits in an amount approximately equal to 16%
6568	6568	9 of the portion of power and energy to be procured by the
6569	6569	10 Agency for the utility. The duration of the contracts
6570	6570	11 procured under this subsection (d-5) shall be for a term
6571	6571	12 of 10 years ending May 31, 2027. The quantity of zero
6572	6572	13 emission credits to be procured under the contracts shall
6573	6573	14 be all of the zero emission credits generated by the zero
6574	6574	15 emission facility in each delivery year; however, if the
6575	6575	16 zero emission facility is owned by more than one entity,
6576	6576	17 then the quantity of zero emission credits to be procured
6577	6577	18 under the contracts shall be the amount of zero emission
6578	6578	19 credits that are generated from the portion of the zero
6579	6579	20 emission facility that is owned by the winning supplier.
6580	6580	21 The 16% value identified in this paragraph (1) is the
6581	6581	22 average of the percentage targets in subparagraph (B) of
6582	6582	23 paragraph (1) of subsection (c) of this Section for the 5
6583	6583	24 delivery years beginning June 1, 2017.
6584	6584	25 The procurement process shall be subject to the
6585	6585	26 following provisions:
6586	6586
6587	6587
6588	6588
6589	6589
6590	6590
6591	6591	HB5514 - 182 - LRB103 39335 CES 69496 b
6592	6592
6593	6593
6594	6594	HB5514- 183 -LRB103 39335 CES 69496 b HB5514 - 183 - LRB103 39335 CES 69496 b
6595	6595	HB5514 - 183 - LRB103 39335 CES 69496 b
6596	6596	1 (A) Those zero emission facilities that intend to
6597	6597	2 participate in the procurement shall submit to the
6598	6598	3 Agency the following eligibility information for each
6599	6599	4 zero emission facility on or before the date
6600	6600	5 established by the Agency:
6601	6601	6 (i) the in-service date and remaining useful
6602	6602	7 life of the zero emission facility;
6603	6603	8 (ii) the amount of power generated annually
6604	6604	9 for each of the years 2005 through 2015, and the
6605	6605	10 projected zero emission credits to be generated
6606	6606	11 over the remaining useful life of the zero
6607	6607	12 emission facility, which shall be used to
6608	6608	13 determine the capability of each facility;
6609	6609	14 (iii) the annual zero emission facility cost
6610	6610	15 projections, expressed on a per megawatthour
6611	6611	16 basis, over the next 6 delivery years, which shall
6612	6612	17 include the following: operation and maintenance
6613	6613	18 expenses; fully allocated overhead costs, which
6614	6614	19 shall be allocated using the methodology developed
6615	6615	20 by the Institute for Nuclear Power Operations;
6616	6616	21 fuel expenditures; non-fuel capital expenditures;
6617	6617	22 spent fuel expenditures; a return on working
6618	6618	23 capital; the cost of operational and market risks
6619	6619	24 that could be avoided by ceasing operation; and
6620	6620	25 any other costs necessary for continued
6621	6621	26 operations, provided that "necessary" means, for
6622	6622
6623	6623
6624	6624
6625	6625
6626	6626
6627	6627	HB5514 - 183 - LRB103 39335 CES 69496 b
6628	6628
6629	6629
6630	6630	HB5514- 184 -LRB103 39335 CES 69496 b HB5514 - 184 - LRB103 39335 CES 69496 b
6631	6631	HB5514 - 184 - LRB103 39335 CES 69496 b
6632	6632	1 purposes of this item (iii), that the costs could
6633	6633	2 reasonably be avoided only by ceasing operations
6634	6634	3 of the zero emission facility; and
6635	6635	4 (iv) a commitment to continue operating, for
6636	6636	5 the duration of the contract or contracts executed
6637	6637	6 under the procurement held under this subsection
6638	6638	7 (d-5), the zero emission facility that produces
6639	6639	8 the zero emission credits to be procured in the
6640	6640	9 procurement.
6641	6641	10 The information described in item (iii) of this
6642	6642	11 subparagraph (A) may be submitted on a confidential
6643	6643	12 basis and shall be treated and maintained by the
6644	6644	13 Agency, the procurement administrator, and the
6645	6645	14 Commission as confidential and proprietary and exempt
6646	6646	15 from disclosure under subparagraphs (a) and (g) of
6647	6647	16 paragraph (1) of Section 7 of the Freedom of
6648	6648	17 Information Act. The Office of Attorney General shall
6649	6649	18 have access to, and maintain the confidentiality of,
6650	6650	19 such information pursuant to Section 6.5 of the
6651	6651	20 Attorney General Act.
6652	6652	21 (B) The price for each zero emission credit
6653	6653	22 procured under this subsection (d-5) for each delivery
6654	6654	23 year shall be in an amount that equals the Social Cost
6655	6655	24 of Carbon, expressed on a price per megawatthour
6656	6656	25 basis. However, to ensure that the procurement remains
6657	6657	26 affordable to retail customers in this State if
6658	6658
6659	6659
6660	6660
6661	6661
6662	6662
6663	6663	HB5514 - 184 - LRB103 39335 CES 69496 b
6664	6664
6665	6665
6666	6666	HB5514- 185 -LRB103 39335 CES 69496 b HB5514 - 185 - LRB103 39335 CES 69496 b
6667	6667	HB5514 - 185 - LRB103 39335 CES 69496 b
6668	6668	1 electricity prices increase, the price in an
6669	6669	2 applicable delivery year shall be reduced below the
6670	6670	3 Social Cost of Carbon by the amount ("Price
6671	6671	4 Adjustment") by which the market price index for the
6672	6672	5 applicable delivery year exceeds the baseline market
6673	6673	6 price index for the consecutive 12-month period ending
6674	6674	7 May 31, 2016. If the Price Adjustment is greater than
6675	6675	8 or equal to the Social Cost of Carbon in an applicable
6676	6676	9 delivery year, then no payments shall be due in that
6677	6677	10 delivery year. The components of this calculation are
6678	6678	11 defined as follows:
6679	6679	12 (i) Social Cost of Carbon: The Social Cost of
6680	6680	13 Carbon is $16.50 per megawatthour, which is based
6681	6681	14 on the U.S. Interagency Working Group on Social
6682	6682	15 Cost of Carbon's price in the August 2016
6683	6683	16 Technical Update using a 3% discount rate,
6684	6684	17 adjusted for inflation for each year of the
6685	6685	18 program. Beginning with the delivery year
6686	6686	19 commencing June 1, 2023, the price per
6687	6687	20 megawatthour shall increase by $1 per
6688	6688	21 megawatthour, and continue to increase by an
6689	6689	22 additional $1 per megawatthour each delivery year
6690	6690	23 thereafter.
6691	6691	24 (ii) Baseline market price index: The baseline
6692	6692	25 market price index for the consecutive 12-month
6693	6693	26 period ending May 31, 2016 is $31.40 per
6694	6694
6695	6695
6696	6696
6697	6697
6698	6698
6699	6699	HB5514 - 185 - LRB103 39335 CES 69496 b
6700	6700
6701	6701
6702	6702	HB5514- 186 -LRB103 39335 CES 69496 b HB5514 - 186 - LRB103 39335 CES 69496 b
6703	6703	HB5514 - 186 - LRB103 39335 CES 69496 b
6704	6704	1 megawatthour, which is based on the sum of (aa)
6705	6705	2 the average day-ahead energy price across all
6706	6706	3 hours of such 12-month period at the PJM
6707	6707	4 Interconnection LLC Northern Illinois Hub, (bb)
6708	6708	5 50% multiplied by the Base Residual Auction, or
6709	6709	6 its successor, capacity price for the rest of the
6710	6710	7 RTO zone group determined by PJM Interconnection
6711	6711	8 LLC, divided by 24 hours per day, and (cc) 50%
6712	6712	9 multiplied by the Planning Resource Auction, or
6713	6713	10 its successor, capacity price for Zone 4
6714	6714	11 determined by the Midcontinent Independent System
6715	6715	12 Operator, Inc., divided by 24 hours per day.
6716	6716	13 (iii) Market price index: The market price
6717	6717	14 index for a delivery year shall be the sum of
6718	6718	15 projected energy prices and projected capacity
6719	6719	16 prices determined as follows:
6720	6720	17 (aa) Projected energy prices: the
6721	6721	18 projected energy prices for the applicable
6722	6722	19 delivery year shall be calculated once for the
6723	6723	20 year using the forward market price for the
6724	6724	21 PJM Interconnection, LLC Northern Illinois
6725	6725	22 Hub. The forward market price shall be
6726	6726	23 calculated as follows: the energy forward
6727	6727	24 prices for each month of the applicable
6728	6728	25 delivery year averaged for each trade date
6729	6729	26 during the calendar year immediately preceding
6730	6730
6731	6731
6732	6732
6733	6733
6734	6734
6735	6735	HB5514 - 186 - LRB103 39335 CES 69496 b
6736	6736
6737	6737
6738	6738	HB5514- 187 -LRB103 39335 CES 69496 b HB5514 - 187 - LRB103 39335 CES 69496 b
6739	6739	HB5514 - 187 - LRB103 39335 CES 69496 b
6740	6740	1 that delivery year to produce a single energy
6741	6741	2 forward price for the delivery year. The
6742	6742	3 forward market price calculation shall use
6743	6743	4 data published by the Intercontinental
6744	6744	5 Exchange, or its successor.
6745	6745	6 (bb) Projected capacity prices:
6746	6746	7 (I) For the delivery years commencing
6747	6747	8 June 1, 2017, June 1, 2018, and June 1,
6748	6748	9 2019, the projected capacity price shall
6749	6749	10 be equal to the sum of (1) 50% multiplied
6750	6750	11 by the Base Residual Auction, or its
6751	6751	12 successor, price for the rest of the RTO
6752	6752	13 zone group as determined by PJM
6753	6753	14 Interconnection LLC, divided by 24 hours
6754	6754	15 per day and, (2) 50% multiplied by the
6755	6755	16 resource auction price determined in the
6756	6756	17 resource auction administered by the
6757	6757	18 Midcontinent Independent System Operator,
6758	6758	19 Inc., in which the largest percentage of
6759	6759	20 load cleared for Local Resource Zone 4,
6760	6760	21 divided by 24 hours per day, and where
6761	6761	22 such price is determined by the
6762	6762	23 Midcontinent Independent System Operator,
6763	6763	24 Inc.
6764	6764	25 (II) For the delivery year commencing
6765	6765	26 June 1, 2020, and each year thereafter,
6766	6766
6767	6767
6768	6768
6769	6769
6770	6770
6771	6771	HB5514 - 187 - LRB103 39335 CES 69496 b
6772	6772
6773	6773
6774	6774	HB5514- 188 -LRB103 39335 CES 69496 b HB5514 - 188 - LRB103 39335 CES 69496 b
6775	6775	HB5514 - 188 - LRB103 39335 CES 69496 b
6776	6776	1 the projected capacity price shall be
6777	6777	2 equal to the sum of (1) 50% multiplied by
6778	6778	3 the Base Residual Auction, or its
6779	6779	4 successor, price for the ComEd zone as
6780	6780	5 determined by PJM Interconnection LLC,
6781	6781	6 divided by 24 hours per day, and (2) 50%
6782	6782	7 multiplied by the resource auction price
6783	6783	8 determined in the resource auction
6784	6784	9 administered by the Midcontinent
6785	6785	10 Independent System Operator, Inc., in
6786	6786	11 which the largest percentage of load
6787	6787	12 cleared for Local Resource Zone 4, divided
6788	6788	13 by 24 hours per day, and where such price
6789	6789	14 is determined by the Midcontinent
6790	6790	15 Independent System Operator, Inc.
6791	6791	16 For purposes of this subsection (d-5):
6792	6792	17 "Rest of the RTO" and "ComEd Zone" shall have
6793	6793	18 the meaning ascribed to them by PJM
6794	6794	19 Interconnection, LLC.
6795	6795	20 "RTO" means regional transmission
6796	6796	21 organization.
6797	6797	22 (C) No later than 45 days after June 1, 2017 (the
6798	6798	23 effective date of Public Act 99-906), the Agency shall
6799	6799	24 publish its proposed zero emission standard
6800	6800	25 procurement plan. The plan shall be consistent with
6801	6801	26 the provisions of this paragraph (1) and shall provide
6802	6802
6803	6803
6804	6804
6805	6805
6806	6806
6807	6807	HB5514 - 188 - LRB103 39335 CES 69496 b
6808	6808
6809	6809
6810	6810	HB5514- 189 -LRB103 39335 CES 69496 b HB5514 - 189 - LRB103 39335 CES 69496 b
6811	6811	HB5514 - 189 - LRB103 39335 CES 69496 b
6812	6812	1 that winning bids shall be selected based on public
6813	6813	2 interest criteria that include, but are not limited
6814	6814	3 to, minimizing carbon dioxide emissions that result
6815	6815	4 from electricity consumed in Illinois and minimizing
6816	6816	5 sulfur dioxide, nitrogen oxide, and particulate matter
6817	6817	6 emissions that adversely affect the citizens of this
6818	6818	7 State. In particular, the selection of winning bids
6819	6819	8 shall take into account the incremental environmental
6820	6820	9 benefits resulting from the procurement, such as any
6821	6821	10 existing environmental benefits that are preserved by
6822	6822	11 the procurements held under Public Act 99-906 and
6823	6823	12 would cease to exist if the procurements were not
6824	6824	13 held, including the preservation of zero emission
6825	6825	14 facilities. The plan shall also describe in detail how
6826	6826	15 each public interest factor shall be considered and
6827	6827	16 weighted in the bid selection process to ensure that
6828	6828	17 the public interest criteria are applied to the
6829	6829	18 procurement and given full effect.
6830	6830	19 For purposes of developing the plan, the Agency
6831	6831	20 shall consider any reports issued by a State agency,
6832	6832	21 board, or commission under House Resolution 1146 of
6833	6833	22 the 98th General Assembly and paragraph (4) of
6834	6834	23 subsection (d) of this Section, as well as publicly
6835	6835	24 available analyses and studies performed by or for
6836	6836	25 regional transmission organizations that serve the
6837	6837	26 State and their independent market monitors.
6838	6838
6839	6839
6840	6840
6841	6841
6842	6842
6843	6843	HB5514 - 189 - LRB103 39335 CES 69496 b
6844	6844
6845	6845
6846	6846	HB5514- 190 -LRB103 39335 CES 69496 b HB5514 - 190 - LRB103 39335 CES 69496 b
6847	6847	HB5514 - 190 - LRB103 39335 CES 69496 b
6848	6848	1 Upon publishing of the zero emission standard
6849	6849	2 procurement plan, copies of the plan shall be posted
6850	6850	3 and made publicly available on the Agency's website.
6851	6851	4 All interested parties shall have 10 days following
6852	6852	5 the date of posting to provide comment to the Agency on
6853	6853	6 the plan. All comments shall be posted to the Agency's
6854	6854	7 website. Following the end of the comment period, but
6855	6855	8 no more than 60 days later than June 1, 2017 (the
6856	6856	9 effective date of Public Act 99-906), the Agency shall
6857	6857	10 revise the plan as necessary based on the comments
6858	6858	11 received and file its zero emission standard
6859	6859	12 procurement plan with the Commission.
6860	6860	13 If the Commission determines that the plan will
6861	6861	14 result in the procurement of cost-effective zero
6862	6862	15 emission credits, then the Commission shall, after
6863	6863	16 notice and hearing, but no later than 45 days after the
6864	6864	17 Agency filed the plan, approve the plan or approve
6865	6865	18 with modification. For purposes of this subsection
6866	6866	19 (d-5), "cost effective" means the projected costs of
6867	6867	20 procuring zero emission credits from zero emission
6868	6868	21 facilities do not cause the limit stated in paragraph
6869	6869	22 (2) of this subsection to be exceeded.
6870	6870	23 (C-5) As part of the Commission's review and
6871	6871	24 acceptance or rejection of the procurement results,
6872	6872	25 the Commission shall, in its public notice of
6873	6873	26 successful bidders:
6874	6874
6875	6875
6876	6876
6877	6877
6878	6878
6879	6879	HB5514 - 190 - LRB103 39335 CES 69496 b
6880	6880
6881	6881
6882	6882	HB5514- 191 -LRB103 39335 CES 69496 b HB5514 - 191 - LRB103 39335 CES 69496 b
6883	6883	HB5514 - 191 - LRB103 39335 CES 69496 b
6884	6884	1 (i) identify how the winning bids satisfy the
6885	6885	2 public interest criteria described in subparagraph
6886	6886	3 (C) of this paragraph (1) of minimizing carbon
6887	6887	4 dioxide emissions that result from electricity
6888	6888	5 consumed in Illinois and minimizing sulfur
6889	6889	6 dioxide, nitrogen oxide, and particulate matter
6890	6890	7 emissions that adversely affect the citizens of
6891	6891	8 this State;
6892	6892	9 (ii) specifically address how the selection of
6893	6893	10 winning bids takes into account the incremental
6894	6894	11 environmental benefits resulting from the
6895	6895	12 procurement, including any existing environmental
6896	6896	13 benefits that are preserved by the procurements
6897	6897	14 held under Public Act 99-906 and would have ceased
6898	6898	15 to exist if the procurements had not been held,
6899	6899	16 such as the preservation of zero emission
6900	6900	17 facilities;
6901	6901	18 (iii) quantify the environmental benefit of
6902	6902	19 preserving the resources identified in item (ii)
6903	6903	20 of this subparagraph (C-5), including the
6904	6904	21 following:
6905	6905	22 (aa) the value of avoided greenhouse gas
6906	6906	23 emissions measured as the product of the zero
6907	6907	24 emission facilities' output over the contract
6908	6908	25 term multiplied by the U.S. Environmental
6909	6909	26 Protection Agency eGrid subregion carbon
6910	6910
6911	6911
6912	6912
6913	6913
6914	6914
6915	6915	HB5514 - 191 - LRB103 39335 CES 69496 b
6916	6916
6917	6917
6918	6918	HB5514- 192 -LRB103 39335 CES 69496 b HB5514 - 192 - LRB103 39335 CES 69496 b
6919	6919	HB5514 - 192 - LRB103 39335 CES 69496 b
6920	6920	1 dioxide emission rate and the U.S. Interagency
6921	6921	2 Working Group on Social Cost of Carbon's price
6922	6922	3 in the August 2016 Technical Update using a 3%
6923	6923	4 discount rate, adjusted for inflation for each
6924	6924	5 delivery year; and
6925	6925	6 (bb) the costs of replacement with other
6926	6926	7 zero carbon dioxide resources, including wind
6927	6927	8 and photovoltaic, based upon the simple
6928	6928	9 average of the following:
6929	6929	10 (I) the price, or if there is more
6930	6930	11 than one price, the average of the prices,
6931	6931	12 paid for renewable energy credits from new
6932	6932	13 utility-scale wind projects in the
6933	6933	14 procurement events specified in item (i)
6934	6934	15 of subparagraph (G) of paragraph (1) of
6935	6935	16 subsection (c) of this Section; and
6936	6936	17 (II) the price, or if there is more
6937	6937	18 than one price, the average of the prices,
6938	6938	19 paid for renewable energy credits from new
6939	6939	20 utility-scale solar projects and
6940	6940	21 brownfield site photovoltaic projects in
6941	6941	22 the procurement events specified in item
6942	6942	23 (ii) of subparagraph (G) of paragraph (1)
6943	6943	24 of subsection (c) of this Section and,
6944	6944	25 after January 1, 2015, renewable energy
6945	6945	26 credits from photovoltaic distributed
6946	6946
6947	6947
6948	6948
6949	6949
6950	6950
6951	6951	HB5514 - 192 - LRB103 39335 CES 69496 b
6952	6952
6953	6953
6954	6954	HB5514- 193 -LRB103 39335 CES 69496 b HB5514 - 193 - LRB103 39335 CES 69496 b
6955	6955	HB5514 - 193 - LRB103 39335 CES 69496 b
6956	6956	1 generation projects in procurement events
6957	6957	2 held under subsection (c) of this Section.
6958	6958	3 Each utility shall enter into binding contractual
6959	6959	4 arrangements with the winning suppliers.
6960	6960	5 The procurement described in this subsection
6961	6961	6 (d-5), including, but not limited to, the execution of
6962	6962	7 all contracts procured, shall be completed no later
6963	6963	8 than May 10, 2017. Based on the effective date of
6964	6964	9 Public Act 99-906, the Agency and Commission may, as
6965	6965	10 appropriate, modify the various dates and timelines
6966	6966	11 under this subparagraph and subparagraphs (C) and (D)
6967	6967	12 of this paragraph (1). The procurement and plan
6968	6968	13 approval processes required by this subsection (d-5)
6969	6969	14 shall be conducted in conjunction with the procurement
6970	6970	15 and plan approval processes required by subsection (c)
6971	6971	16 of this Section and Section 16-111.5 of the Public
6972	6972	17 Utilities Act, to the extent practicable.
6973	6973	18 Notwithstanding whether a procurement event is
6974	6974	19 conducted under Section 16-111.5 of the Public
6975	6975	20 Utilities Act, the Agency shall immediately initiate a
6976	6976	21 procurement process on June 1, 2017 (the effective
6977	6977	22 date of Public Act 99-906).
6978	6978	23 (D) Following the procurement event described in
6979	6979	24 this paragraph (1) and consistent with subparagraph
6980	6980	25 (B) of this paragraph (1), the Agency shall calculate
6981	6981	26 the payments to be made under each contract for the
6982	6982
6983	6983
6984	6984
6985	6985
6986	6986
6987	6987	HB5514 - 193 - LRB103 39335 CES 69496 b
6988	6988
6989	6989
6990	6990	HB5514- 194 -LRB103 39335 CES 69496 b HB5514 - 194 - LRB103 39335 CES 69496 b
6991	6991	HB5514 - 194 - LRB103 39335 CES 69496 b
6992	6992	1 next delivery year based on the market price index for
6993	6993	2 that delivery year. The Agency shall publish the
6994	6994	3 payment calculations no later than May 25, 2017 and
6995	6995	4 every May 25 thereafter.
6996	6996	5 (E) Notwithstanding the requirements of this
6997	6997	6 subsection (d-5), the contracts executed under this
6998	6998	7 subsection (d-5) shall provide that the zero emission
6999	6999	8 facility may, as applicable, suspend or terminate
7000	7000	9 performance under the contracts in the following
7001	7001	10 instances:
7002	7002	11 (i) A zero emission facility shall be excused
7003	7003	12 from its performance under the contract for any
7004	7004	13 cause beyond the control of the resource,
7005	7005	14 including, but not restricted to, acts of God,
7006	7006	15 flood, drought, earthquake, storm, fire,
7007	7007	16 lightning, epidemic, war, riot, civil disturbance
7008	7008	17 or disobedience, labor dispute, labor or material
7009	7009	18 shortage, sabotage, acts of public enemy,
7010	7010	19 explosions, orders, regulations or restrictions
7011	7011	20 imposed by governmental, military, or lawfully
7012	7012	21 established civilian authorities, which, in any of
7013	7013	22 the foregoing cases, by exercise of commercially
7014	7014	23 reasonable efforts the zero emission facility
7015	7015	24 could not reasonably have been expected to avoid,
7016	7016	25 and which, by the exercise of commercially
7017	7017	26 reasonable efforts, it has been unable to
7018	7018
7019	7019
7020	7020
7021	7021
7022	7022
7023	7023	HB5514 - 194 - LRB103 39335 CES 69496 b
7024	7024
7025	7025
7026	7026	HB5514- 195 -LRB103 39335 CES 69496 b HB5514 - 195 - LRB103 39335 CES 69496 b
7027	7027	HB5514 - 195 - LRB103 39335 CES 69496 b
7028	7028	1 overcome. In such event, the zero emission
7029	7029	2 facility shall be excused from performance for the
7030	7030	3 duration of the event, including, but not limited
7031	7031	4 to, delivery of zero emission credits, and no
7032	7032	5 payment shall be due to the zero emission facility
7033	7033	6 during the duration of the event.
7034	7034	7 (ii) A zero emission facility shall be
7035	7035	8 permitted to terminate the contract if legislation
7036	7036	9 is enacted into law by the General Assembly that
7037	7037	10 imposes or authorizes a new tax, special
7038	7038	11 assessment, or fee on the generation of
7039	7039	12 electricity, the ownership or leasehold of a
7040	7040	13 generating unit, or the privilege or occupation of
7041	7041	14 such generation, ownership, or leasehold of
7042	7042	15 generation units by a zero emission facility.
7043	7043	16 However, the provisions of this item (ii) do not
7044	7044	17 apply to any generally applicable tax, special
7045	7045	18 assessment or fee, or requirements imposed by
7046	7046	19 federal law.
7047	7047	20 (iii) A zero emission facility shall be
7048	7048	21 permitted to terminate the contract in the event
7049	7049	22 that the resource requires capital expenditures in
7050	7050	23 excess of $40,000,000 that were neither known nor
7051	7051	24 reasonably foreseeable at the time it executed the
7052	7052	25 contract and that a prudent owner or operator of
7053	7053	26 such resource would not undertake.
7054	7054
7055	7055
7056	7056
7057	7057
7058	7058
7059	7059	HB5514 - 195 - LRB103 39335 CES 69496 b
7060	7060
7061	7061
7062	7062	HB5514- 196 -LRB103 39335 CES 69496 b HB5514 - 196 - LRB103 39335 CES 69496 b
7063	7063	HB5514 - 196 - LRB103 39335 CES 69496 b
7064	7064	1 (iv) A zero emission facility shall be
7065	7065	2 permitted to terminate the contract in the event
7066	7066	3 the Nuclear Regulatory Commission terminates the
7067	7067	4 resource's license.
7068	7068	5 (F) If the zero emission facility elects to
7069	7069	6 terminate a contract under subparagraph (E) of this
7070	7070	7 paragraph (1), then the Commission shall reopen the
7071	7071	8 docket in which the Commission approved the zero
7072	7072	9 emission standard procurement plan under subparagraph
7073	7073	10 (C) of this paragraph (1) and, after notice and
7074	7074	11 hearing, enter an order acknowledging the contract
7075	7075	12 termination election if such termination is consistent
7076	7076	13 with the provisions of this subsection (d-5).
7077	7077	14 (2) For purposes of this subsection (d-5), the amount
7078	7078	15 paid per kilowatthour means the total amount paid for
7079	7079	16 electric service expressed on a per kilowatthour basis.
7080	7080	17 For purposes of this subsection (d-5), the total amount
7081	7081	18 paid for electric service includes, without limitation,
7082	7082	19 amounts paid for supply, transmission, distribution,
7083	7083	20 surcharges, and add-on taxes.
7084	7084	21 Notwithstanding the requirements of this subsection
7085	7085	22 (d-5), the contracts executed under this subsection (d-5)
7086	7086	23 shall provide that the total of zero emission credits
7087	7087	24 procured under a procurement plan shall be subject to the
7088	7088	25 limitations of this paragraph (2). For each delivery year,
7089	7089	26 the contractual volume receiving payments in such year
7090	7090
7091	7091
7092	7092
7093	7093
7094	7094
7095	7095	HB5514 - 196 - LRB103 39335 CES 69496 b
7096	7096
7097	7097
7098	7098	HB5514- 197 -LRB103 39335 CES 69496 b HB5514 - 197 - LRB103 39335 CES 69496 b
7099	7099	HB5514 - 197 - LRB103 39335 CES 69496 b
7100	7100	1 shall be reduced for all retail customers based on the
7101	7101	2 amount necessary to limit the net increase that delivery
7102	7102	3 year to the costs of those credits included in the amounts
7103	7103	4 paid by eligible retail customers in connection with
7104	7104	5 electric service to no more than 1.65% of the amount paid
7105	7105	6 per kilowatthour by eligible retail customers during the
7106	7106	7 year ending May 31, 2009. The result of this computation
7107	7107	8 shall apply to and reduce the procurement for all retail
7108	7108	9 customers, and all those customers shall pay the same
7109	7109	10 single, uniform cents per kilowatthour charge under
7110	7110	11 subsection (k) of Section 16-108 of the Public Utilities
7111	7111	12 Act. To arrive at a maximum dollar amount of zero emission
7112	7112	13 credits to be paid for the particular delivery year, the
7113	7113	14 resulting per kilowatthour amount shall be applied to the
7114	7114	15 actual amount of kilowatthours of electricity delivered by
7115	7115	16 the electric utility in the delivery year immediately
7116	7116	17 prior to the procurement, to all retail customers in its
7117	7117	18 service territory. Unpaid contractual volume for any
7118	7118	19 delivery year shall be paid in any subsequent delivery
7119	7119	20 year in which such payments can be made without exceeding
7120	7120	21 the amount specified in this paragraph (2). The
7121	7121	22 calculations required by this paragraph (2) shall be made
7122	7122	23 only once for each procurement plan year. Once the
7123	7123	24 determination as to the amount of zero emission credits to
7124	7124	25 be paid is made based on the calculations set forth in this
7125	7125	26 paragraph (2), no subsequent rate impact determinations
7126	7126
7127	7127
7128	7128
7129	7129
7130	7130
7131	7131	HB5514 - 197 - LRB103 39335 CES 69496 b
7132	7132
7133	7133
7134	7134	HB5514- 198 -LRB103 39335 CES 69496 b HB5514 - 198 - LRB103 39335 CES 69496 b
7135	7135	HB5514 - 198 - LRB103 39335 CES 69496 b
7136	7136	1 shall be made and no adjustments to those contract amounts
7137	7137	2 shall be allowed. All costs incurred under those contracts
7138	7138	3 and in implementing this subsection (d-5) shall be
7139	7139	4 recovered by the electric utility as provided in this
7140	7140	5 Section.
7141	7141	6 No later than June 30, 2019, the Commission shall
7142	7142	7 review the limitation on the amount of zero emission
7143	7143	8 credits procured under this subsection (d-5) and report to
7144	7144	9 the General Assembly its findings as to whether that
7145	7145	10 limitation unduly constrains the procurement of
7146	7146	11 cost-effective zero emission credits.
7147	7147	12 (3) Six years after the execution of a contract under
7148	7148	13 this subsection (d-5), the Agency shall determine whether
7149	7149	14 the actual zero emission credit payments received by the
7150	7150	15 supplier over the 6-year period exceed the Average ZEC
7151	7151	16 Payment. In addition, at the end of the term of a contract
7152	7152	17 executed under this subsection (d-5), or at the time, if
7153	7153	18 any, a zero emission facility's contract is terminated
7154	7154	19 under subparagraph (E) of paragraph (1) of this subsection
7155	7155	20 (d-5), then the Agency shall determine whether the actual
7156	7156	21 zero emission credit payments received by the supplier
7157	7157	22 over the term of the contract exceed the Average ZEC
7158	7158	23 Payment, after taking into account any amounts previously
7159	7159	24 credited back to the utility under this paragraph (3). If
7160	7160	25 the Agency determines that the actual zero emission credit
7161	7161	26 payments received by the supplier over the relevant period
7162	7162
7163	7163
7164	7164
7165	7165
7166	7166
7167	7167	HB5514 - 198 - LRB103 39335 CES 69496 b
7168	7168
7169	7169
7170	7170	HB5514- 199 -LRB103 39335 CES 69496 b HB5514 - 199 - LRB103 39335 CES 69496 b
7171	7171	HB5514 - 199 - LRB103 39335 CES 69496 b
7172	7172	1 exceed the Average ZEC Payment, then the supplier shall
7173	7173	2 credit the difference back to the utility. The amount of
7174	7174	3 the credit shall be remitted to the applicable electric
7175	7175	4 utility no later than 120 days after the Agency's
7176	7176	5 determination, which the utility shall reflect as a credit
7177	7177	6 on its retail customer bills as soon as practicable;
7178	7178	7 however, the credit remitted to the utility shall not
7179	7179	8 exceed the total amount of payments received by the
7180	7180	9 facility under its contract.
7181	7181	10 For purposes of this Section, the Average ZEC Payment
7182	7182	11 shall be calculated by multiplying the quantity of zero
7183	7183	12 emission credits delivered under the contract times the
7184	7184	13 average contract price. The average contract price shall
7185	7185	14 be determined by subtracting the amount calculated under
7186	7186	15 subparagraph (B) of this paragraph (3) from the amount
7187	7187	16 calculated under subparagraph (A) of this paragraph (3),
7188	7188	17 as follows:
7189	7189	18 (A) The average of the Social Cost of Carbon, as
7190	7190	19 defined in subparagraph (B) of paragraph (1) of this
7191	7191	20 subsection (d-5), during the term of the contract.
7192	7192	21 (B) The average of the market price indices, as
7193	7193	22 defined in subparagraph (B) of paragraph (1) of this
7194	7194	23 subsection (d-5), during the term of the contract,
7195	7195	24 minus the baseline market price index, as defined in
7196	7196	25 subparagraph (B) of paragraph (1) of this subsection
7197	7197	26 (d-5).
7198	7198
7199	7199
7200	7200
7201	7201
7202	7202
7203	7203	HB5514 - 199 - LRB103 39335 CES 69496 b
7204	7204
7205	7205
7206	7206	HB5514- 200 -LRB103 39335 CES 69496 b HB5514 - 200 - LRB103 39335 CES 69496 b
7207	7207	HB5514 - 200 - LRB103 39335 CES 69496 b
7208	7208	1 If the subtraction yields a negative number, then the
7209	7209	2 Average ZEC Payment shall be zero.
7210	7210	3 (4) Cost-effective zero emission credits procured from
7211	7211	4 zero emission facilities shall satisfy the applicable
7212	7212	5 definitions set forth in Section 1-10 of this Act.
7213	7213	6 (5) The electric utility shall retire all zero
7214	7214	7 emission credits used to comply with the requirements of
7215	7215	8 this subsection (d-5).
7216	7216	9 (6) Electric utilities shall be entitled to recover
7217	7217	10 all of the costs associated with the procurement of zero
7218	7218	11 emission credits through an automatic adjustment clause
7219	7219	12 tariff in accordance with subsection (k) and (m) of
7220	7220	13 Section 16-108 of the Public Utilities Act, and the
7221	7221	14 contracts executed under this subsection (d-5) shall
7222	7222	15 provide that the utilities' payment obligations under such
7223	7223	16 contracts shall be reduced if an adjustment is required
7224	7224	17 under subsection (m) of Section 16-108 of the Public
7225	7225	18 Utilities Act.
7226	7226	19 (7) This subsection (d-5) shall become inoperative on
7227	7227	20 January 1, 2028.
7228	7228	21 (d-10) Nuclear Plant Assistance; carbon mitigation
7229	7229	22 credits.
7230	7230	23 (1) The General Assembly finds:
7231	7231	24 (A) The health, welfare, and prosperity of all
7232	7232	25 Illinois citizens require that the State of Illinois act
7233	7233	26 to avoid and not increase carbon emissions from electric
7234	7234
7235	7235
7236	7236
7237	7237
7238	7238
7239	7239	HB5514 - 200 - LRB103 39335 CES 69496 b
7240	7240
7241	7241
7242	7242	HB5514- 201 -LRB103 39335 CES 69496 b HB5514 - 201 - LRB103 39335 CES 69496 b
7243	7243	HB5514 - 201 - LRB103 39335 CES 69496 b
7244	7244	1 generation sources while continuing to ensure affordable,
7245	7245	2 stable, and reliable electricity to all citizens.
7246	7246	3 (B) Absent immediate action by the State to preserve
7247	7247	4 existing carbon-free energy resources, those resources may
7248	7248	5 retire, and the electric generation needs of Illinois'
7249	7249	6 retail customers may be met instead by facilities that
7250	7250	7 emit significant amounts of carbon pollution and other
7251	7251	8 harmful air pollutants at a high social and economic cost
7252	7252	9 until Illinois is able to develop other forms of clean
7253	7253	10 energy.
7254	7254	11 (C) The General Assembly finds that nuclear power
7255	7255	12 generation is necessary for the State's transition to 100%
7256	7256	13 clean energy, and ensuring continued operation of nuclear
7257	7257	14 plants advances environmental and public health interests
7258	7258	15 through providing carbon-free electricity while reducing
7259	7259	16 the air pollution profile of the Illinois energy
7260	7260	17 generation fleet.
7261	7261	18 (D) The clean energy attributes of nuclear generation
7262	7262	19 facilities support the State in its efforts to achieve
7263	7263	20 100% clean energy.
7264	7264	21 (E) The State currently invests in various forms of
7265	7265	22 clean energy, including, but not limited to, renewable
7266	7266	23 energy, energy efficiency, and low-emission vehicles,
7267	7267	24 among others.
7268	7268	25 (F) The Environmental Protection Agency commissioned
7269	7269	26 an independent audit which provided a detailed assessment
7270	7270
7271	7271
7272	7272
7273	7273
7274	7274
7275	7275	HB5514 - 201 - LRB103 39335 CES 69496 b
7276	7276
7277	7277
7278	7278	HB5514- 202 -LRB103 39335 CES 69496 b HB5514 - 202 - LRB103 39335 CES 69496 b
7279	7279	HB5514 - 202 - LRB103 39335 CES 69496 b
7280	7280	1 of the financial condition of the Illinois nuclear fleet
7281	7281	2 to evaluate its financial viability and whether the
7282	7282	3 environmental benefits of such resources were at risk. The
7283	7283	4 report identified the risk of losing the environmental
7284	7284	5 benefits of several specific nuclear units. The report
7285	7285	6 also identified that the LaSalle County Generating Station
7286	7286	7 will continue to operate through 2026 and therefore is not
7287	7287	8 eligible to participate in the carbon mitigation credit
7288	7288	9 program.
7289	7289	10 (G) Nuclear plants provide carbon-free energy, which
7290	7290	11 helps to avoid many health-related negative impacts for
7291	7291	12 Illinois residents.
7292	7292	13 (H) The procurement of carbon mitigation credits
7293	7293	14 representing the environmental benefits of carbon-free
7294	7294	15 generation will further the State's efforts at achieving
7295	7295	16 100% clean energy and decarbonizing the electricity sector
7296	7296	17 in a safe, reliable, and affordable manner. Further, the
7297	7297	18 procurement of carbon emission credits will enhance the
7298	7298	19 health and welfare of Illinois residents through decreased
7299	7299	20 reliance on more highly polluting generation.
7300	7300	21 (I) The General Assembly therefore finds it necessary
7301	7301	22 to establish carbon mitigation credits to ensure decreased
7302	7302	23 reliance on more carbon-intensive energy resources, for
7303	7303	24 transitioning to a fully decarbonized electricity sector,
7304	7304	25 and to help ensure health and welfare of the State's
7305	7305	26 residents.
7306	7306
7307	7307
7308	7308
7309	7309
7310	7310
7311	7311	HB5514 - 202 - LRB103 39335 CES 69496 b
7312	7312
7313	7313
7314	7314	HB5514- 203 -LRB103 39335 CES 69496 b HB5514 - 203 - LRB103 39335 CES 69496 b
7315	7315	HB5514 - 203 - LRB103 39335 CES 69496 b
7316	7316	1 (2) As used in this subsection:
7317	7317	2 "Baseline costs" means costs used to establish a customer
7318	7318	3 protection cap that have been evaluated through an independent
7319	7319	4 audit of a carbon-free energy resource conducted by the
7320	7320	5 Environmental Protection Agency that evaluated projected
7321	7321	6 annual costs for operation and maintenance expenses; fully
7322	7322	7 allocated overhead costs, which shall be allocated using the
7323	7323	8 methodology developed by the Institute for Nuclear Power
7324	7324	9 Operations; fuel expenditures; nonfuel capital expenditures;
7325	7325	10 spent fuel expenditures; a return on working capital; the cost
7326	7326	11 of operational and market risks that could be avoided by
7327	7327	12 ceasing operation; and any other costs necessary for continued
7328	7328	13 operations, provided that "necessary" means, for purposes of
7329	7329	14 this definition, that the costs could reasonably be avoided
7330	7330	15 only by ceasing operations of the carbon-free energy resource.
7331	7331	16 "Carbon mitigation credit" means a tradable credit that
7332	7332	17 represents the carbon emission reduction attributes of one
7333	7333	18 megawatt-hour of energy produced from a carbon-free energy
7334	7334	19 resource.
7335	7335	20 "Carbon-free energy resource" means a generation facility
7336	7336	21 that: (1) is fueled by nuclear power; and (2) is
7337	7337	22 interconnected to PJM Interconnection, LLC.
7338	7338	23 (3) Procurement.
7339	7339	24 (A) Beginning with the delivery year commencing on
7340	7340	25 June 1, 2022, the Agency shall, for electric utilities
7341	7341	26 serving at least 3,000,000 retail customers in the State,
7342	7342
7343	7343
7344	7344
7345	7345
7346	7346
7347	7347	HB5514 - 203 - LRB103 39335 CES 69496 b
7348	7348
7349	7349
7350	7350	HB5514- 204 -LRB103 39335 CES 69496 b HB5514 - 204 - LRB103 39335 CES 69496 b
7351	7351	HB5514 - 204 - LRB103 39335 CES 69496 b
7352	7352	1 seek to procure contracts for no more than approximately
7353	7353	2 54,500,000 cost-effective carbon mitigation credits from
7354	7354	3 carbon-free energy resources because such credits are
7355	7355	4 necessary to support current levels of carbon-free energy
7356	7356	5 generation and ensure the State meets its carbon dioxide
7357	7357	6 emissions reduction goals. The Agency shall not make a
7358	7358	7 partial award of a contract for carbon mitigation credits
7359	7359	8 covering a fractional amount of a carbon-free energy
7360	7360	9 resource's projected output.
7361	7361	10 (B) Each carbon-free energy resource that intends to
7362	7362	11 participate in a procurement shall be required to submit
7363	7363	12 to the Agency the following information for the resource
7364	7364	13 on or before the date established by the Agency:
7365	7365	14 (i) the in-service date and remaining useful life
7366	7366	15 of the carbon-free energy resource;
7367	7367	16 (ii) the amount of power generated annually for
7368	7368	17 each of the past 10 years, which shall be used to
7369	7369	18 determine the capability of each facility;
7370	7370	19 (iii) a commitment to be reflected in any contract
7371	7371	20 entered into pursuant to this subsection (d-10) to
7372	7372	21 continue operating the carbon-free energy resource at
7373	7373	22 a capacity factor of at least 88% annually on average
7374	7374	23 for the duration of the contract or contracts executed
7375	7375	24 under the procurement held under this subsection
7376	7376	25 (d-10), except in an instance described in
7377	7377	26 subparagraph (E) of paragraph (1) of subsection (d-5)
7378	7378
7379	7379
7380	7380
7381	7381
7382	7382
7383	7383	HB5514 - 204 - LRB103 39335 CES 69496 b
7384	7384
7385	7385
7386	7386	HB5514- 205 -LRB103 39335 CES 69496 b HB5514 - 205 - LRB103 39335 CES 69496 b
7387	7387	HB5514 - 205 - LRB103 39335 CES 69496 b
7388	7388	1 of this Section or made impracticable as a result of
7389	7389	2 compliance with law or regulation;
7390	7390	3 (iv) financial need and the risk of loss of the
7391	7391	4 environmental benefits of such resource, which shall
7392	7392	5 include the following information:
7393	7393	6 (I) the carbon-free energy resource's cost
7394	7394	7 projections, expressed on a per megawatt-hour
7395	7395	8 basis, over the next 5 delivery years, which shall
7396	7396	9 include the following: operation and maintenance
7397	7397	10 expenses; fully allocated overhead costs, which
7398	7398	11 shall be allocated using the methodology developed
7399	7399	12 by the Institute for Nuclear Power Operations;
7400	7400	13 fuel expenditures; nonfuel capital expenditures;
7401	7401	14 spent fuel expenditures; a return on working
7402	7402	15 capital; the cost of operational and market risks
7403	7403	16 that could be avoided by ceasing operation; and
7404	7404	17 any other costs necessary for continued
7405	7405	18 operations, provided that "necessary" means, for
7406	7406	19 purposes of this subitem (I), that the costs could
7407	7407	20 reasonably be avoided only by ceasing operations
7408	7408	21 of the carbon-free energy resource; and
7409	7409	22 (II) the carbon-free energy resource's revenue
7410	7410	23 projections, including energy, capacity, ancillary
7411	7411	24 services, any other direct State support, known or
7412	7412	25 anticipated federal attribute credits, known or
7413	7413	26 anticipated tax credits, and any other direct
7414	7414
7415	7415
7416	7416
7417	7417
7418	7418
7419	7419	HB5514 - 205 - LRB103 39335 CES 69496 b
7420	7420
7421	7421
7422	7422	HB5514- 206 -LRB103 39335 CES 69496 b HB5514 - 206 - LRB103 39335 CES 69496 b
7423	7423	HB5514 - 206 - LRB103 39335 CES 69496 b
7424	7424	1 federal support.
7425	7425	2 The information described in this subparagraph (B) may
7426	7426	3 be submitted on a confidential basis and shall be treated
7427	7427	4 and maintained by the Agency, the procurement
7428	7428	5 administrator, and the Commission as confidential and
7429	7429	6 proprietary and exempt from disclosure under subparagraphs
7430	7430	7 (a) and (g) of paragraph (1) of Section 7 of the Freedom of
7431	7431	8 Information Act. The Office of the Attorney General shall
7432	7432	9 have access to, and maintain the confidentiality of, such
7433	7433	10 information pursuant to Section 6.5 of the Attorney
7434	7434	11 General Act.
7435	7435	12 (C) The Agency shall solicit bids for the contracts
7436	7436	13 described in this subsection (d-10) from carbon-free
7437	7437	14 energy resources that have satisfied the requirements of
7438	7438	15 subparagraph (B) of this paragraph (3). The contracts
7439	7439	16 procured pursuant to a procurement event shall reflect,
7440	7440	17 and be subject to, the following terms, requirements, and
7441	7441	18 limitations:
7442	7442	19 (i) Contracts are for delivery of carbon
7443	7443	20 mitigation credits, and are not energy or capacity
7444	7444	21 sales contracts requiring physical delivery. Pursuant
7445	7445	22 to item (iii), contract payments shall fully deduct
7446	7446	23 the value of any monetized federal production tax
7447	7447	24 credits, credits issued pursuant to a federal clean
7448	7448	25 energy standard, and other federal credits if
7449	7449	26 applicable.
7450	7450
7451	7451
7452	7452
7453	7453
7454	7454
7455	7455	HB5514 - 206 - LRB103 39335 CES 69496 b
7456	7456
7457	7457
7458	7458	HB5514- 207 -LRB103 39335 CES 69496 b HB5514 - 207 - LRB103 39335 CES 69496 b
7459	7459	HB5514 - 207 - LRB103 39335 CES 69496 b
7460	7460	1 (ii) Contracts for carbon mitigation credits shall
7461	7461	2 commence with the delivery year beginning on June 1,
7462	7462	3 2022 and shall be for a term of 5 delivery years
7463	7463	4 concluding on May 31, 2027.
7464	7464	5 (iii) The price per carbon mitigation credit to be
7465	7465	6 paid under a contract for a given delivery year shall
7466	7466	7 be equal to an accepted bid price less the sum of:
7467	7467	8 (I) one of the following energy price indices,
7468	7468	9 selected by the bidder at the time of the bid for
7469	7469	10 the term of the contract:
7470	7470	11 (aa) the weighted-average hourly day-ahead
7471	7471	12 price for the applicable delivery year at the
7472	7472	13 busbar of all resources procured pursuant to
7473	7473	14 this subsection (d-10), weighted by actual
7474	7474	15 production from the resources; or
7475	7475	16 (bb) the projected energy price for the
7476	7476	17 PJM Interconnection, LLC Northern Illinois Hub
7477	7477	18 for the applicable delivery year determined
7478	7478	19 according to subitem (aa) of item (iii) of
7479	7479	20 subparagraph (B) of paragraph (1) of
7480	7480	21 subsection (d-5).
7481	7481	22 (II) the Base Residual Auction Capacity Price
7482	7482	23 for the ComEd zone as determined by PJM
7483	7483	24 Interconnection, LLC, divided by 24 hours per day,
7484	7484	25 for the applicable delivery year for the first 3
7485	7485	26 delivery years, and then any subsequent delivery
7486	7486
7487	7487
7488	7488
7489	7489
7490	7490
7491	7491	HB5514 - 207 - LRB103 39335 CES 69496 b
7492	7492
7493	7493
7494	7494	HB5514- 208 -LRB103 39335 CES 69496 b HB5514 - 208 - LRB103 39335 CES 69496 b
7495	7495	HB5514 - 208 - LRB103 39335 CES 69496 b
7496	7496	1 years unless the PJM Interconnection, LLC applies
7497	7497	2 the Minimum Offer Price Rule to participating
7498	7498	3 carbon-free energy resources because they supply
7499	7499	4 carbon mitigation credits pursuant to this Section
7500	7500	5 at which time, upon notice by the carbon-free
7501	7501	6 energy resource to the Commission and subject to
7502	7502	7 the Commission's confirmation, the value under
7503	7503	8 this subitem shall be zero, as further described
7504	7504	9 in the carbon mitigation credit procurement plan;
7505	7505	10 and
7506	7506	11 (III) any value of monetized federal tax
7507	7507	12 credits, direct payments, or similar subsidy
7508	7508	13 provided to the carbon-free energy resource from
7509	7509	14 any unit of government that is not already
7510	7510	15 reflected in energy prices.
7511	7511	16 If the price-per-megawatt-hour calculation
7512	7512	17 performed under item (iii) of this subparagraph (C)
7513	7513	18 for a given delivery year results in a net positive
7514	7514	19 value, then the electric utility counterparty to the
7515	7515	20 contract shall multiply such net value by the
7516	7516	21 applicable contract quantity and remit the amount to
7517	7517	22 the supplier.
7518	7518	23 To protect retail customers from retail rate
7519	7519	24 impacts that may arise upon the initiation of carbon
7520	7520	25 policy changes, if the price-per-megawatt-hour
7521	7521	26 calculation performed under item (iii) of this
7522	7522
7523	7523
7524	7524
7525	7525
7526	7526
7527	7527	HB5514 - 208 - LRB103 39335 CES 69496 b
7528	7528
7529	7529
7530	7530	HB5514- 209 -LRB103 39335 CES 69496 b HB5514 - 209 - LRB103 39335 CES 69496 b
7531	7531	HB5514 - 209 - LRB103 39335 CES 69496 b
7532	7532	1 subparagraph (C) for a given delivery year results in
7533	7533	2 a net negative value, then the supplier counterparty
7534	7534	3 to the contract shall multiply such net value by the
7535	7535	4 applicable contract quantity and remit such amount to
7536	7536	5 the electric utility counterparty. The electric
7537	7537	6 utility shall reflect such amounts remitted by
7538	7538	7 suppliers as a credit on its retail customer bills as
7539	7539	8 soon as practicable.
7540	7540	9 (iv) To ensure that retail customers in Northern
7541	7541	10 Illinois do not pay more for carbon mitigation credits
7542	7542	11 than the value such credits provide, and
7543	7543	12 notwithstanding the provisions of this subsection
7544	7544	13 (d-10), the Agency shall not accept bids for contracts
7545	7545	14 that exceed a customer protection cap equal to the
7546	7546	15 baseline costs of carbon-free energy resources.
7547	7547	16 The baseline costs for the applicable year shall
7548	7548	17 be the following:
7549	7549	18 (I) For the delivery year beginning June 1,
7550	7550	19 2022, the baseline costs shall be an amount equal
7551	7551	20 to $30.30 per megawatt-hour.
7552	7552	21 (II) For the delivery year beginning June 1,
7553	7553	22 2023, the baseline costs shall be an amount equal
7554	7554	23 to $32.50 per megawatt-hour.
7555	7555	24 (III) For the delivery year beginning June 1,
7556	7556	25 2024, the baseline costs shall be an amount equal
7557	7557	26 to $33.43 per megawatt-hour.
7558	7558
7559	7559
7560	7560
7561	7561
7562	7562
7563	7563	HB5514 - 209 - LRB103 39335 CES 69496 b
7564	7564
7565	7565
7566	7566	HB5514- 210 -LRB103 39335 CES 69496 b HB5514 - 210 - LRB103 39335 CES 69496 b
7567	7567	HB5514 - 210 - LRB103 39335 CES 69496 b
7568	7568	1 (IV) For the delivery year beginning June 1,
7569	7569	2 2025, the baseline costs shall be an amount equal
7570	7570	3 to $33.50 per megawatt-hour.
7571	7571	4 (V) For the delivery year beginning June 1,
7572	7572	5 2026, the baseline costs shall be an amount equal
7573	7573	6 to $34.50 per megawatt-hour.
7574	7574	7 An Environmental Protection Agency consultant
7575	7575	8 forecast, included in a report issued April 14, 2021,
7576	7576	9 projects that a carbon-free energy resource has the
7577	7577	10 opportunity to earn on average approximately $30.28
7578	7578	11 per megawatt-hour, for the sale of energy and capacity
7579	7579	12 during the time period between 2022 and 2027.
7580	7580	13 Therefore, the sale of carbon mitigation credits
7581	7581	14 provides the opportunity to receive an additional
7582	7582	15 amount per megawatt-hour in addition to the projected
7583	7583	16 prices for energy and capacity.
7584	7584	17 Although actual energy and capacity prices may
7585	7585	18 vary from year-to-year, the General Assembly finds
7586	7586	19 that this customer protection cap will help ensure
7587	7587	20 that the cost of carbon mitigation credits will be
7588	7588	21 less than its value, based upon the social cost of
7589	7589	22 carbon identified in the Technical Support Document
7590	7590	23 issued in February 2021 by the U.S. Interagency
7591	7591	24 Working Group on Social Cost of Greenhouse Gases and
7592	7592	25 the PJM Interconnection, LLC carbon dioxide marginal
7593	7593	26 emission rate for 2020, and that a carbon-free energy
7594	7594
7595	7595
7596	7596
7597	7597
7598	7598
7599	7599	HB5514 - 210 - LRB103 39335 CES 69496 b
7600	7600
7601	7601
7602	7602	HB5514- 211 -LRB103 39335 CES 69496 b HB5514 - 211 - LRB103 39335 CES 69496 b
7603	7603	HB5514 - 211 - LRB103 39335 CES 69496 b
7604	7604	1 resource receiving payment for carbon mitigation
7605	7605	2 credits receives no more than necessary to keep those
7606	7606	3 units in operation.
7607	7607	4 (D) No later than 7 days after the effective date of
7608	7608	5 this amendatory Act of the 102nd General Assembly, the
7609	7609	6 Agency shall publish its proposed carbon mitigation credit
7610	7610	7 procurement plan. The Plan shall provide that winning bids
7611	7611	8 shall be selected by taking into consideration which
7612	7612	9 resources best match public interest criteria that
7613	7613	10 include, but are not limited to, minimizing carbon dioxide
7614	7614	11 emissions that result from electricity consumed in
7615	7615	12 Illinois and minimizing sulfur dioxide, nitrogen oxide,
7616	7616	13 and particulate matter emissions that adversely affect the
7617	7617	14 citizens of this State. The selection of winning bids
7618	7618	15 shall also take into account the incremental environmental
7619	7619	16 benefits resulting from the procurement or procurements,
7620	7620	17 such as any existing environmental benefits that are
7621	7621	18 preserved by a procurement held under this subsection
7622	7622	19 (d-10) and would cease to exist if the procurement were
7623	7623	20 not held, including the preservation of carbon-free energy
7624	7624	21 resources. For those bidders having the same public
7625	7625	22 interest criteria score, the relative ranking of such
7626	7626	23 bidders shall be determined by price. The Plan shall
7627	7627	24 describe in detail how each public interest factor shall
7628	7628	25 be considered and weighted in the bid selection process to
7629	7629	26 ensure that the public interest criteria are applied to
7630	7630
7631	7631
7632	7632
7633	7633
7634	7634
7635	7635	HB5514 - 211 - LRB103 39335 CES 69496 b
7636	7636
7637	7637
7638	7638	HB5514- 212 -LRB103 39335 CES 69496 b HB5514 - 212 - LRB103 39335 CES 69496 b
7639	7639	HB5514 - 212 - LRB103 39335 CES 69496 b
7640	7640	1 the procurement. The Plan shall, to the extent practical
7641	7641	2 and permissible by federal law, ensure that successful
7642	7642	3 bidders make commercially reasonable efforts to apply for
7643	7643	4 federal tax credits, direct payments, or similar subsidy
7644	7644	5 programs that support carbon-free generation and for which
7645	7645	6 the successful bidder is eligible. Upon publishing of the
7646	7646	7 carbon mitigation credit procurement plan, copies of the
7647	7647	8 plan shall be posted and made publicly available on the
7648	7648	9 Agency's website. All interested parties shall have 7 days
7649	7649	10 following the date of posting to provide comment to the
7650	7650	11 Agency on the plan. All comments shall be posted to the
7651	7651	12 Agency's website. Following the end of the comment period,
7652	7652	13 but no more than 19 days later than the effective date of
7653	7653	14 this amendatory Act of the 102nd General Assembly, the
7654	7654	15 Agency shall revise the plan as necessary based on the
7655	7655	16 comments received and file its carbon mitigation credit
7656	7656	17 procurement plan with the Commission.
7657	7657	18 (E) If the Commission determines that the plan is
7658	7658	19 likely to result in the procurement of cost-effective
7659	7659	20 carbon mitigation credits, then the Commission shall,
7660	7660	21 after notice and hearing and opportunity for comment, but
7661	7661	22 no later than 42 days after the Agency filed the plan,
7662	7662	23 approve the plan or approve it with modification. For
7663	7663	24 purposes of this subsection (d-10), "cost-effective" means
7664	7664	25 carbon mitigation credits that are procured from
7665	7665	26 carbon-free energy resources at prices that are within the
7666	7666
7667	7667
7668	7668
7669	7669
7670	7670
7671	7671	HB5514 - 212 - LRB103 39335 CES 69496 b
7672	7672
7673	7673
7674	7674	HB5514- 213 -LRB103 39335 CES 69496 b HB5514 - 213 - LRB103 39335 CES 69496 b
7675	7675	HB5514 - 213 - LRB103 39335 CES 69496 b
7676	7676	1 limits specified in this paragraph (3). As part of the
7677	7677	2 Commission's review and acceptance or rejection of the
7678	7678	3 procurement results, the Commission shall, in its public
7679	7679	4 notice of successful bidders:
7680	7680	5 (i) identify how the selected carbon-free energy
7681	7681	6 resources satisfy the public interest criteria
7682	7682	7 described in this paragraph (3) of minimizing carbon
7683	7683	8 dioxide emissions that result from electricity
7684	7684	9 consumed in Illinois and minimizing sulfur dioxide,
7685	7685	10 nitrogen oxide, and particulate matter emissions that
7686	7686	11 adversely affect the citizens of this State;
7687	7687	12 (ii) specifically address how the selection of
7688	7688	13 carbon-free energy resources takes into account the
7689	7689	14 incremental environmental benefits resulting from the
7690	7690	15 procurement, including any existing environmental
7691	7691	16 benefits that are preserved by the procurements held
7692	7692	17 under this amendatory Act of the 102nd General
7693	7693	18 Assembly and would have ceased to exist if the
7694	7694	19 procurements had not been held, such as the
7695	7695	20 preservation of carbon-free energy resources;
7696	7696	21 (iii) quantify the environmental benefit of
7697	7697	22 preserving the carbon-free energy resources procured
7698	7698	23 pursuant to this subsection (d-10), including the
7699	7699	24 following:
7700	7700	25 (I) an assessment value of avoided greenhouse
7701	7701	26 gas emissions measured as the product of the
7702	7702
7703	7703
7704	7704
7705	7705
7706	7706
7707	7707	HB5514 - 213 - LRB103 39335 CES 69496 b
7708	7708
7709	7709
7710	7710	HB5514- 214 -LRB103 39335 CES 69496 b HB5514 - 214 - LRB103 39335 CES 69496 b
7711	7711	HB5514 - 214 - LRB103 39335 CES 69496 b
7712	7712	1 carbon-free energy resources' output over the
7713	7713	2 contract term, using generally accepted
7714	7714	3 methodologies for the valuation of avoided
7715	7715	4 emissions; and
7716	7716	5 (II) an assessment of costs of replacement
7717	7717	6 with other carbon-free energy resources and
7718	7718	7 renewable energy resources, including wind and
7719	7719	8 photovoltaic generation, based upon an assessment
7720	7720	9 of the prices paid for renewable energy credits
7721	7721	10 through programs and procurements conducted
7722	7722	11 pursuant to subsection (c) of Section 1-75 of this
7723	7723	12 Act, and the additional storage necessary to
7724	7724	13 produce the same or similar capability of matching
7725	7725	14 customer usage patterns.
7726	7726	15 (F) The procurements described in this paragraph (3),
7727	7727	16 including, but not limited to, the execution of all
7728	7728	17 contracts procured, shall be completed no later than
7729	7729	18 December 3, 2021. The procurement and plan approval
7730	7730	19 processes required by this paragraph (3) shall be
7731	7731	20 conducted in conjunction with the procurement and plan
7732	7732	21 approval processes required by Section 16-111.5 of the
7733	7733	22 Public Utilities Act, to the extent practicable. However,
7734	7734	23 the Agency and Commission may, as appropriate, modify the
7735	7735	24 various dates and timelines under this subparagraph and
7736	7736	25 subparagraphs (D) and (E) of this paragraph (3) to meet
7737	7737	26 the December 3, 2021 contract execution deadline.
7738	7738
7739	7739
7740	7740
7741	7741
7742	7742
7743	7743	HB5514 - 214 - LRB103 39335 CES 69496 b
7744	7744
7745	7745
7746	7746	HB5514- 215 -LRB103 39335 CES 69496 b HB5514 - 215 - LRB103 39335 CES 69496 b
7747	7747	HB5514 - 215 - LRB103 39335 CES 69496 b
7748	7748	1 Following the completion of such procurements, and
7749	7749	2 consistent with this paragraph (3), the Agency shall
7750	7750	3 calculate the payments to be made under each contract in a
7751	7751	4 timely fashion.
7752	7752	5 (F-1) Costs incurred by the electric utility pursuant
7753	7753	6 to a contract authorized by this subsection (d-10) shall
7754	7754	7 be deemed prudently incurred and reasonable in amount, and
7755	7755	8 the electric utility shall be entitled to full cost
7756	7756	9 recovery pursuant to a tariff or tariffs filed with the
7757	7757	10 Commission.
7758	7758	11 (G) The counterparty electric utility shall retire all
7759	7759	12 carbon mitigation credits used to comply with the
7760	7760	13 requirements of this subsection (d-10).
7761	7761	14 (H) If a carbon-free energy resource is sold to
7762	7762	15 another owner, the rights, obligations, and commitments
7763	7763	16 under this subsection (d-10) shall continue to the
7764	7764	17 subsequent owner.
7765	7765	18 (I) This subsection (d-10) shall become inoperative on
7766	7766	19 January 1, 2028.
7767	7767	20 (e) The draft procurement plans are subject to public
7768	7768	21 comment, as required by Section 16-111.5 of the Public
7769	7769	22 Utilities Act.
7770	7770	23 (f) The Agency shall submit the final procurement plan to
7771	7771	24 the Commission. The Agency shall revise a procurement plan if
7772	7772	25 the Commission determines that it does not meet the standards
7773	7773	26 set forth in Section 16-111.5 of the Public Utilities Act.
7774	7774
7775	7775
7776	7776
7777	7777
7778	7778
7779	7779	HB5514 - 215 - LRB103 39335 CES 69496 b
7780	7780
7781	7781
7782	7782	HB5514- 216 -LRB103 39335 CES 69496 b HB5514 - 216 - LRB103 39335 CES 69496 b
7783	7783	HB5514 - 216 - LRB103 39335 CES 69496 b
7784	7784	1 (g) The Agency shall assess fees to each affected utility
7785	7785	2 to recover the costs incurred in preparation of the annual
7786	7786	3 procurement plan for the utility.
7787	7787	4 (h) The Agency shall assess fees to each bidder to recover
7788	7788	5 the costs incurred in connection with a competitive
7789	7789	6 procurement process.
7790	7790	7 (i) A renewable energy credit, carbon emission credit,
7791	7791	8 zero emission credit, or carbon mitigation credit can only be
7792	7792	9 used once to comply with a single portfolio or other standard
7793	7793	10 as set forth in subsection (c), subsection (d), or subsection
7794	7794	11 (d-5) of this Section, respectively. A renewable energy
7795	7795	12 credit, carbon emission credit, zero emission credit, or
7796	7796	13 carbon mitigation credit cannot be used to satisfy the
7797	7797	14 requirements of more than one standard. If more than one type
7798	7798	15 of credit is issued for the same megawatt hour of energy, only
7799	7799	16 one credit can be used to satisfy the requirements of a single
7800	7800	17 standard. After such use, the credit must be retired together
7801	7801	18 with any other credits issued for the same megawatt hour of
7802	7802	19 energy.
7803	7803	20 (Source: P.A. 102-662, eff. 9-15-21; 103-380, eff. 1-1-24;
7804	7804	21 103-580, eff. 12-8-23.)
7805	7805	22 Section 10. The Public Utilities Act is amended by
7806	7806	23 changing Sections 16-108 and 16-111.5 as follows:
7807	7807	24 (220 ILCS 5/16-108)
7808	7808
7809	7809
7810	7810
7811	7811
7812	7812
7813	7813	HB5514 - 216 - LRB103 39335 CES 69496 b
7814	7814
7815	7815
7816	7816	HB5514- 217 -LRB103 39335 CES 69496 b HB5514 - 217 - LRB103 39335 CES 69496 b
7817	7817	HB5514 - 217 - LRB103 39335 CES 69496 b
7818	7818	1 Sec. 16-108. Recovery of costs associated with the
7819	7819	2 provision of delivery and other services.
7820	7820	3 (a) An electric utility shall file a delivery services
7821	7821	4 tariff with the Commission at least 210 days prior to the date
7822	7822	5 that it is required to begin offering such services pursuant
7823	7823	6 to this Act. An electric utility shall provide the components
7824	7824	7 of delivery services that are subject to the jurisdiction of
7825	7825	8 the Federal Energy Regulatory Commission at the same prices,
7826	7826	9 terms and conditions set forth in its applicable tariff as
7827	7827	10 approved or allowed into effect by that Commission. The
7828	7828	11 Commission shall otherwise have the authority pursuant to
7829	7829	12 Article IX to review, approve, and modify the prices, terms
7830	7830	13 and conditions of those components of delivery services not
7831	7831	14 subject to the jurisdiction of the Federal Energy Regulatory
7832	7832	15 Commission, including the authority to determine the extent to
7833	7833	16 which such delivery services should be offered on an unbundled
7834	7834	17 basis. In making any such determination the Commission shall
7835	7835	18 consider, at a minimum, the effect of additional unbundling on
7836	7836	19 (i) the objective of just and reasonable rates, (ii) electric
7837	7837	20 utility employees, and (iii) the development of competitive
7838	7838	21 markets for electric energy services in Illinois.
7839	7839	22 (b) The Commission shall enter an order approving, or
7840	7840	23 approving as modified, the delivery services tariff no later
7841	7841	24 than 30 days prior to the date on which the electric utility
7842	7842	25 must commence offering such services. The Commission may
7843	7843	26 subsequently modify such tariff pursuant to this Act.
7844	7844
7845	7845
7846	7846
7847	7847
7848	7848
7849	7849	HB5514 - 217 - LRB103 39335 CES 69496 b
7850	7850
7851	7851
7852	7852	HB5514- 218 -LRB103 39335 CES 69496 b HB5514 - 218 - LRB103 39335 CES 69496 b
7853	7853	HB5514 - 218 - LRB103 39335 CES 69496 b
7854	7854	1 (c) The electric utility's tariffs shall define the
7855	7855	2 classes of its customers for purposes of delivery services
7856	7856	3 charges. Delivery services shall be priced and made available
7857	7857	4 to all retail customers electing delivery services in each
7858	7858	5 such class on a nondiscriminatory basis regardless of whether
7859	7859	6 the retail customer chooses the electric utility, an affiliate
7860	7860	7 of the electric utility, or another entity as its supplier of
7861	7861	8 electric power and energy. Charges for delivery services shall
7862	7862	9 be cost based, and shall allow the electric utility to recover
7863	7863	10 the costs of providing delivery services through its charges
7864	7864	11 to its delivery service customers that use the facilities and
7865	7865	12 services associated with such costs. Such costs shall include
7866	7866	13 the costs of owning, operating and maintaining transmission
7867	7867	14 and distribution facilities. The Commission shall also be
7868	7868	15 authorized to consider whether, and if so to what extent, the
7869	7869	16 following costs are appropriately included in the electric
7870	7870	17 utility's delivery services rates: (i) the costs of that
7871	7871	18 portion of generation facilities used for the production and
7872	7872	19 absorption of reactive power in order that retail customers
7873	7873	20 located in the electric utility's service area can receive
7874	7874	21 electric power and energy from suppliers other than the
7875	7875	22 electric utility, and (ii) the costs associated with the use
7876	7876	23 and redispatch of generation facilities to mitigate
7877	7877	24 constraints on the transmission or distribution system in
7878	7878	25 order that retail customers located in the electric utility's
7879	7879	26 service area can receive electric power and energy from
7880	7880
7881	7881
7882	7882
7883	7883
7884	7884
7885	7885	HB5514 - 218 - LRB103 39335 CES 69496 b
7886	7886
7887	7887
7888	7888	HB5514- 219 -LRB103 39335 CES 69496 b HB5514 - 219 - LRB103 39335 CES 69496 b
7889	7889	HB5514 - 219 - LRB103 39335 CES 69496 b
7890	7890	1 suppliers other than the electric utility. Nothing in this
7891	7891	2 subsection shall be construed as directing the Commission to
7892	7892	3 allocate any of the costs described in (i) or (ii) that are
7893	7893	4 found to be appropriately included in the electric utility's
7894	7894	5 delivery services rates to any particular customer group or
7895	7895	6 geographic area in setting delivery services rates.
7896	7896	7 (d) The Commission shall establish charges, terms and
7897	7897	8 conditions for delivery services that are just and reasonable
7898	7898	9 and shall take into account customer impacts when establishing
7899	7899	10 such charges. In establishing charges, terms and conditions
7900	7900	11 for delivery services, the Commission shall take into account
7901	7901	12 voltage level differences. A retail customer shall have the
7902	7902	13 option to request to purchase electric service at any delivery
7903	7903	14 service voltage reasonably and technically feasible from the
7904	7904	15 electric facilities serving that customer's premises provided
7905	7905	16 that there are no significant adverse impacts upon system
7906	7906	17 reliability or system efficiency. A retail customer shall also
7907	7907	18 have the option to request to purchase electric service at any
7908	7908	19 point of delivery that is reasonably and technically feasible
7909	7909	20 provided that there are no significant adverse impacts on
7910	7910	21 system reliability or efficiency. Such requests shall not be
7911	7911	22 unreasonably denied.
7912	7912	23 (e) Electric utilities shall recover the costs of
7913	7913	24 installing, operating or maintaining facilities for the
7914	7914	25 particular benefit of one or more delivery services customers,
7915	7915	26 including without limitation any costs incurred in complying
7916	7916
7917	7917
7918	7918
7919	7919
7920	7920
7921	7921	HB5514 - 219 - LRB103 39335 CES 69496 b
7922	7922
7923	7923
7924	7924	HB5514- 220 -LRB103 39335 CES 69496 b HB5514 - 220 - LRB103 39335 CES 69496 b
7925	7925	HB5514 - 220 - LRB103 39335 CES 69496 b
7926	7926	1 with a customer's request to be served at a different voltage
7927	7927	2 level, directly from the retail customer or customers for
7928	7928	3 whose benefit the costs were incurred, to the extent such
7929	7929	4 costs are not recovered through the charges referred to in
7930	7930	5 subsections (c) and (d) of this Section.
7931	7931	6 (f) An electric utility shall be entitled but not required
7932	7932	7 to implement transition charges in conjunction with the
7933	7933	8 offering of delivery services pursuant to Section 16-104. If
7934	7934	9 an electric utility implements transition charges, it shall
7935	7935	10 implement such charges for all delivery services customers and
7936	7936	11 for all customers described in subsection (h), but shall not
7937	7937	12 implement transition charges for power and energy that a
7938	7938	13 retail customer takes from cogeneration or self-generation
7939	7939	14 facilities located on that retail customer's premises, if such
7940	7940	15 facilities meet the following criteria:
7941	7941	16 (i) the cogeneration or self-generation facilities
7942	7942	17 serve a single retail customer and are located on that
7943	7943	18 retail customer's premises (for purposes of this
7944	7944	19 subparagraph and subparagraph (ii), an industrial or
7945	7945	20 manufacturing retail customer and a third party contractor
7946	7946	21 that is served by such industrial or manufacturing
7947	7947	22 customer through such retail customer's own electrical
7948	7948	23 distribution facilities under the circumstances described
7949	7949	24 in subsection (vi) of the definition of "alternative
7950	7950	25 retail electric supplier" set forth in Section 16-102,
7951	7951	26 shall be considered a single retail customer);
7952	7952
7953	7953
7954	7954
7955	7955
7956	7956
7957	7957	HB5514 - 220 - LRB103 39335 CES 69496 b
7958	7958
7959	7959
7960	7960	HB5514- 221 -LRB103 39335 CES 69496 b HB5514 - 221 - LRB103 39335 CES 69496 b
7961	7961	HB5514 - 221 - LRB103 39335 CES 69496 b
7962	7962	1 (ii) the cogeneration or self-generation facilities
7963	7963	2 either (A) are sized pursuant to generally accepted
7964	7964	3 engineering standards for the retail customer's electrical
7965	7965	4 load at that premises (taking into account standby or
7966	7966	5 other reliability considerations related to that retail
7967	7967	6 customer's operations at that site) or (B) if the facility
7968	7968	7 is a cogeneration facility located on the retail
7969	7969	8 customer's premises, the retail customer is the thermal
7970	7970	9 host for that facility and the facility has been designed
7971	7971	10 to meet that retail customer's thermal energy requirements
7972	7972	11 resulting in electrical output beyond that retail
7973	7973	12 customer's electrical demand at that premises, comply with
7974	7974	13 the operating and efficiency standards applicable to
7975	7975	14 "qualifying facilities" specified in title 18 Code of
7976	7976	15 Federal Regulations Section 292.205 as in effect on the
7977	7977	16 effective date of this amendatory Act of 1999;
7978	7978	17 (iii) the retail customer on whose premises the
7979	7979	18 facilities are located either has an exclusive right to
7980	7980	19 receive, and corresponding obligation to pay for, all of
7981	7981	20 the electrical capacity of the facility, or in the case of
7982	7982	21 a cogeneration facility that has been designed to meet the
7983	7983	22 retail customer's thermal energy requirements at that
7984	7984	23 premises, an identified amount of the electrical capacity
7985	7985	24 of the facility, over a minimum 5-year period; and
7986	7986	25 (iv) if the cogeneration facility is sized for the
7987	7987	26 retail customer's thermal load at that premises but
7988	7988
7989	7989
7990	7990
7991	7991
7992	7992
7993	7993	HB5514 - 221 - LRB103 39335 CES 69496 b
7994	7994
7995	7995
7996	7996	HB5514- 222 -LRB103 39335 CES 69496 b HB5514 - 222 - LRB103 39335 CES 69496 b
7997	7997	HB5514 - 222 - LRB103 39335 CES 69496 b
7998	7998	1 exceeds the electrical load, any sales of excess power or
7999	7999	2 energy are made only at wholesale, are subject to the
8000	8000	3 jurisdiction of the Federal Energy Regulatory Commission,
8001	8001	4 and are not for the purpose of circumventing the
8002	8002	5 provisions of this subsection (f).
8003	8003	6 If a generation facility located at a retail customer's
8004	8004	7 premises does not meet the above criteria, an electric utility
8005	8005	8 implementing transition charges shall implement a transition
8006	8006	9 charge until December 31, 2006 for any power and energy taken
8007	8007	10 by such retail customer from such facility as if such power and
8008	8008	11 energy had been delivered by the electric utility. Provided,
8009	8009	12 however, that an industrial retail customer that is taking
8010	8010	13 power from a generation facility that does not meet the above
8011	8011	14 criteria but that is located on such customer's premises will
8012	8012	15 not be subject to a transition charge for the power and energy
8013	8013	16 taken by such retail customer from such generation facility if
8014	8014	17 the facility does not serve any other retail customer and
8015	8015	18 either was installed on behalf of the customer and for its own
8016	8016	19 use prior to January 1, 1997, or is both predominantly fueled
8017	8017	20 by byproducts of such customer's manufacturing process at such
8018	8018	21 premises and sells or offers an average of 300 megawatts or
8019	8019	22 more of electricity produced from such generation facility
8020	8020	23 into the wholesale market. Such charges shall be calculated as
8021	8021	24 provided in Section 16-102, and shall be collected on each
8022	8022	25 kilowatt-hour delivered under a delivery services tariff to a
8023	8023	26 retail customer from the date the customer first takes
8024	8024
8025	8025
8026	8026
8027	8027
8028	8028
8029	8029	HB5514 - 222 - LRB103 39335 CES 69496 b
8030	8030
8031	8031
8032	8032	HB5514- 223 -LRB103 39335 CES 69496 b HB5514 - 223 - LRB103 39335 CES 69496 b
8033	8033	HB5514 - 223 - LRB103 39335 CES 69496 b
8034	8034	1 delivery services until December 31, 2006 except as provided
8035	8035	2 in subsection (h) of this Section. Provided, however, that an
8036	8036	3 electric utility, other than an electric utility providing
8037	8037	4 service to at least 1,000,000 customers in this State on
8038	8038	5 January 1, 1999, shall be entitled to petition for entry of an
8039	8039	6 order by the Commission authorizing the electric utility to
8040	8040	7 implement transition charges for an additional period ending
8041	8041	8 no later than December 31, 2008. The electric utility shall
8042	8042	9 file its petition with supporting evidence no earlier than 16
8043	8043	10 months, and no later than 12 months, prior to December 31,
8044	8044	11 2006. The Commission shall hold a hearing on the electric
8045	8045	12 utility's petition and shall enter its order no later than 8
8046	8046	13 months after the petition is filed. The Commission shall
8047	8047	14 determine whether and to what extent the electric utility
8048	8048	15 shall be authorized to implement transition charges for an
8049	8049	16 additional period. The Commission may authorize the electric
8050	8050	17 utility to implement transition charges for some or all of the
8051	8051	18 additional period, and shall determine the mitigation factors
8052	8052	19 to be used in implementing such transition charges; provided,
8053	8053	20 that the Commission shall not authorize mitigation factors
8054	8054	21 less than 110% of those in effect during the 12 months ended
8055	8055	22 December 31, 2006. In making its determination, the Commission
8056	8056	23 shall consider the following factors: the necessity to
8057	8057	24 implement transition charges for an additional period in order
8058	8058	25 to maintain the financial integrity of the electric utility;
8059	8059	26 the prudence of the electric utility's actions in reducing its
8060	8060
8061	8061
8062	8062
8063	8063
8064	8064
8065	8065	HB5514 - 223 - LRB103 39335 CES 69496 b
8066	8066
8067	8067
8068	8068	HB5514- 224 -LRB103 39335 CES 69496 b HB5514 - 224 - LRB103 39335 CES 69496 b
8069	8069	HB5514 - 224 - LRB103 39335 CES 69496 b
8070	8070	1 costs since the effective date of this amendatory Act of 1997;
8071	8071	2 the ability of the electric utility to provide safe, adequate
8072	8072	3 and reliable service to retail customers in its service area;
8073	8073	4 and the impact on competition of allowing the electric utility
8074	8074	5 to implement transition charges for the additional period.
8075	8075	6 (g) The electric utility shall file tariffs that establish
8076	8076	7 the transition charges to be paid by each class of customers to
8077	8077	8 the electric utility in conjunction with the provision of
8078	8078	9 delivery services. The electric utility's tariffs shall define
8079	8079	10 the classes of its customers for purposes of calculating
8080	8080	11 transition charges. The electric utility's tariffs shall
8081	8081	12 provide for the calculation of transition charges on a
8082	8082	13 customer-specific basis for any retail customer whose average
8083	8083	14 monthly maximum electrical demand on the electric utility's
8084	8084	15 system during the 6 months with the customer's highest monthly
8085	8085	16 maximum electrical demands equals or exceeds 3.0 megawatts for
8086	8086	17 electric utilities having more than 1,000,000 customers, and
8087	8087	18 for other electric utilities for any customer that has an
8088	8088	19 average monthly maximum electrical demand on the electric
8089	8089	20 utility's system of one megawatt or more, and (A) for which
8090	8090	21 there exists data on the customer's usage during the 3 years
8091	8091	22 preceding the date that the customer became eligible to take
8092	8092	23 delivery services, or (B) for which there does not exist data
8093	8093	24 on the customer's usage during the 3 years preceding the date
8094	8094	25 that the customer became eligible to take delivery services,
8095	8095	26 if in the electric utility's reasonable judgment there exists
8096	8096
8097	8097
8098	8098
8099	8099
8100	8100
8101	8101	HB5514 - 224 - LRB103 39335 CES 69496 b
8102	8102
8103	8103
8104	8104	HB5514- 225 -LRB103 39335 CES 69496 b HB5514 - 225 - LRB103 39335 CES 69496 b
8105	8105	HB5514 - 225 - LRB103 39335 CES 69496 b
8106	8106	1 comparable usage information or a sufficient basis to develop
8107	8107	2 such information, and further provided that the electric
8108	8108	3 utility can require customers for which an individual
8109	8109	4 calculation is made to sign contracts that set forth the
8110	8110	5 transition charges to be paid by the customer to the electric
8111	8111	6 utility pursuant to the tariff.
8112	8112	7 (h) An electric utility shall also be entitled to file
8113	8113	8 tariffs that allow it to collect transition charges from
8114	8114	9 retail customers in the electric utility's service area that
8115	8115	10 do not take delivery services but that take electric power or
8116	8116	11 energy from an alternative retail electric supplier or from an
8117	8117	12 electric utility other than the electric utility in whose
8118	8118	13 service area the customer is located. Such charges shall be
8119	8119	14 calculated, in accordance with the definition of transition
8120	8120	15 charges in Section 16-102, for the period of time that the
8121	8121	16 customer would be obligated to pay transition charges if it
8122	8122	17 were taking delivery services, except that no deduction for
8123	8123	18 delivery services revenues shall be made in such calculation,
8124	8124	19 and usage data from the customer's class shall be used where
8125	8125	20 historical usage data is not available for the individual
8126	8126	21 customer. The customer shall be obligated to pay such charges
8127	8127	22 on a lump sum basis on or before the date on which the customer
8128	8128	23 commences to take service from the alternative retail electric
8129	8129	24 supplier or other electric utility, provided, that the
8130	8130	25 electric utility in whose service area the customer is located
8131	8131	26 shall offer the customer the option of signing a contract
8132	8132
8133	8133
8134	8134
8135	8135
8136	8136
8137	8137	HB5514 - 225 - LRB103 39335 CES 69496 b
8138	8138
8139	8139
8140	8140	HB5514- 226 -LRB103 39335 CES 69496 b HB5514 - 226 - LRB103 39335 CES 69496 b
8141	8141	HB5514 - 226 - LRB103 39335 CES 69496 b
8142	8142	1 pursuant to which the customer pays such charges ratably over
8143	8143	2 the period in which the charges would otherwise have applied.
8144	8144	3 (i) An electric utility shall be entitled to add to the
8145	8145	4 bills of delivery services customers charges pursuant to
8146	8146	5 Sections 9-221, 9-222 (except as provided in Section 9-222.1),
8147	8147	6 and Section 16-114 of this Act, Section 5-5 of the Electricity
8148	8148	7 Infrastructure Maintenance Fee Law, Section 6-5 of the
8149	8149	8 Renewable Energy, Energy Efficiency, and Coal Resources
8150	8150	9 Development Law of 1997, and Section 13 of the Energy
8151	8151	10 Assistance Act.
8152	8152	11 (i-5) An electric utility required to impose the Coal to
8153	8153	12 Solar and Energy Storage Initiative Charge provided for in
8154	8154	13 subsection (c-5) of Section 1-75 of the Illinois Power Agency
8155	8155	14 Act shall add such charge to the bills of its delivery services
8156	8156	15 customers pursuant to the terms of a tariff conforming to the
8157	8157	16 requirements of subsection (c-5) of Section 1-75 of the
8158	8158	17 Illinois Power Agency Act and this subsection (i-5) and filed
8159	8159	18 with and approved by the Commission. The electric utility
8160	8160	19 shall file its proposed tariff with the Commission on or
8161	8161	20 before July 1, 2022 to be effective, after review and approval
8162	8162	21 or modification by the Commission, beginning January 1, 2023.
8163	8163	22 On or before December 1, 2022, the Commission shall review the
8164	8164	23 electric utility's proposed tariff, including by conducting a
8165	8165	24 docketed proceeding if deemed necessary by the Commission, and
8166	8166	25 shall approve the proposed tariff or direct the electric
8167	8167	26 utility to make modifications the Commission finds necessary
8168	8168
8169	8169
8170	8170
8171	8171
8172	8172
8173	8173	HB5514 - 226 - LRB103 39335 CES 69496 b
8174	8174
8175	8175
8176	8176	HB5514- 227 -LRB103 39335 CES 69496 b HB5514 - 227 - LRB103 39335 CES 69496 b
8177	8177	HB5514 - 227 - LRB103 39335 CES 69496 b
8178	8178	1 for the tariff to conform to the requirements of subsection
8179	8179	2 (c-5) of Section 1-75 of the Illinois Power Agency Act and this
8180	8180	3 subsection (i-5). The electric utility's tariff shall provide
8181	8181	4 for imposition of the Coal to Solar and Energy Storage
8182	8182	5 Initiative Charge on a per-kilowatthour basis to all
8183	8183	6 kilowatthours delivered by the electric utility to its
8184	8184	7 delivery services customers. The tariff shall provide for the
8185	8185	8 calculation of the Coal to Solar and Energy Storage Initiative
8186	8186	9 Charge to be in effect for the year beginning January 1, 2023
8187	8187	10 and each year beginning January 1 thereafter, sufficient to
8188	8188	11 collect the electric utility's estimated payment obligations
8189	8189	12 for the delivery year beginning the following June 1 under
8190	8190	13 contracts for purchase of renewable energy credits entered
8191	8191	14 into pursuant to subsection (c-5) of Section 1-75 of the
8192	8192	15 Illinois Power Agency Act and the obligations of the
8193	8193	16 Department of Commerce and Economic Opportunity, or any
8194	8194	17 successor department or agency, which for purposes of this
8195	8195	18 subsection (i-5) shall be referred to as the Department, to
8196	8196	19 make grant payments during such delivery year from the Coal to
8197	8197	20 Solar and Energy Storage Initiative Fund pursuant to grant
8198	8198	21 contracts entered into pursuant to subsection (c-5) of Section
8199	8199	22 1-75 of the Illinois Power Agency Act, and using the electric
8200	8200	23 utility's kilowatthour deliveries to its delivery services
8201	8201	24 customers during the delivery year ended May 31 of the
8202	8202	25 preceding calendar year. On or before November 1 of each year
8203	8203	26 beginning November 1, 2022, the Department shall notify the
8204	8204
8205	8205
8206	8206
8207	8207
8208	8208
8209	8209	HB5514 - 227 - LRB103 39335 CES 69496 b
8210	8210
8211	8211
8212	8212	HB5514- 228 -LRB103 39335 CES 69496 b HB5514 - 228 - LRB103 39335 CES 69496 b
8213	8213	HB5514 - 228 - LRB103 39335 CES 69496 b
8214	8214	1 electric utilities of the amount of the Department's estimated
8215	8215	2 obligations for grant payments during the delivery year
8216	8216	3 beginning the following June 1 pursuant to grant contracts
8217	8217	4 entered into pursuant to subsection (c-5) of Section 1-75 of
8218	8218	5 the Illinois Power Agency Act; and each electric utility shall
8219	8219	6 incorporate in the calculation of its Coal to Solar and Energy
8220	8220	7 Storage Initiative Charge the fractional portion of the
8221	8221	8 Department's estimated obligations equal to the electric
8222	8222	9 utility's kilowatthour deliveries to its delivery services
8223	8223	10 customers in the delivery year ended the preceding May 31
8224	8224	11 divided by the aggregate deliveries of both electric utilities
8225	8225	12 to delivery services customers in such delivery year. The
8226	8226	13 electric utility shall remit on a monthly basis to the State
8227	8227	14 Treasurer, for deposit in the Coal to Solar and Energy Storage
8228	8228	15 Initiative Fund provided for in subsection (c-5) of Section
8229	8229	16 1-75 of the Illinois Power Agency Act, the electric utility's
8230	8230	17 collections of the Coal to Solar and Energy Storage Initiative
8231	8231	18 Charge estimated to be needed by the Department for grant
8232	8232	19 payments pursuant to grant contracts entered into pursuant to
8233	8233	20 subsection (c-5) of Section 1-75 of the Illinois Power Agency
8234	8234	21 Act. The initial charge under the electric utility's tariff
8235	8235	22 shall be effective for kilowatthours delivered beginning
8236	8236	23 January 1, 2023, and thereafter shall be revised to be
8237	8237	24 effective January 1, 2024 and each January 1 thereafter, based
8238	8238	25 on the payment obligations for the delivery year beginning the
8239	8239	26 following June 1. The tariff shall provide for the electric
8240	8240
8241	8241
8242	8242
8243	8243
8244	8244
8245	8245	HB5514 - 228 - LRB103 39335 CES 69496 b
8246	8246
8247	8247
8248	8248	HB5514- 229 -LRB103 39335 CES 69496 b HB5514 - 229 - LRB103 39335 CES 69496 b
8249	8249	HB5514 - 229 - LRB103 39335 CES 69496 b
8250	8250	1 utility to make an annual filing with the Commission on or
8251	8251	2 before November 15 of each year, beginning in 2023, setting
8252	8252	3 forth the Coal to Solar and Energy Storage Initiative Charge
8253	8253	4 to be in effect for the year beginning the following January 1.
8254	8254	5 The electric utility's tariff shall also provide that the
8255	8255	6 electric utility shall make a filing with the Commission on or
8256	8256	7 before August 1 of each year beginning in 2024 setting forth a
8257	8257	8 reconciliation, for the delivery year ended the preceding May
8258	8258	9 31, of the electric utility's collections of the Coal to Solar
8259	8259	10 and Energy Storage Initiative Charge against actual payments
8260	8260	11 for renewable energy credits pursuant to contracts entered
8261	8261	12 into, and the actual grant payments by the Department pursuant
8262	8262	13 to grant contracts entered into, pursuant to subsection (c-5)
8263	8263	14 of Section 1-75 of the Illinois Power Agency Act. The tariff
8264	8264	15 shall provide that any excess or shortfall of collections to
8265	8265	16 payments shall be deducted from or added to, on a
8266	8266	17 per-kilowatthour basis, the Coal to Solar and Energy Storage
8267	8267	18 Initiative Charge, over the 6-month period beginning October 1
8268	8268	19 of that calendar year.
8269	8269	20 (i-7) The electric utility shall be entitled to recover
8270	8270	21 through tariffed charges all of the costs associated with
8271	8271	22 payment under contracts for purchase of high voltage direct
8272	8272	23 current renewable energy credits entered into pursuant to
8273	8273	24 subsection (c-7) of Section 1-75 of the Illinois Power Agency
8274	8274	25 Act. An electric utility required to impose the dispatchable
8275	8275	26 and reliable renewable energy charge provided for in
8276	8276
8277	8277
8278	8278
8279	8279
8280	8280
8281	8281	HB5514 - 229 - LRB103 39335 CES 69496 b
8282	8282
8283	8283
8284	8284	HB5514- 230 -LRB103 39335 CES 69496 b HB5514 - 230 - LRB103 39335 CES 69496 b
8285	8285	HB5514 - 230 - LRB103 39335 CES 69496 b
8286	8286	1 subsection (c-7) of Section 1-75 of the Illinois Power Agency
8287	8287	2 Act shall add such charge to the bills of its delivery services
8288	8288	3 customers pursuant to the terms of a tariff conforming to the
8289	8289	4 requirements of subsection (c-7) of Section 1-75 of the
8290	8290	5 Illinois Power Agency Act and this subsection (i-7) and filed
8291	8291	6 with and approved by the Commission. The electric utility
8292	8292	7 shall file its proposed tariff with the Commission on or
8293	8293	8 before February 1, 2025 to be effective, after review and
8294	8294	9 approval or modification by the Commission, beginning January
8295	8295	10 1, 2026. On or before January 1, 2026, the Commission shall
8296	8296	11 review the electric utility's proposed tariff, including by
8297	8297	12 conducting a docketed proceeding if deemed necessary by the
8298	8298	13 Commission, and shall approve the proposed tariff or direct
8299	8299	14 the electric utility to make modifications the Commission
8300	8300	15 finds necessary for the tariff to conform to the requirements
8301	8301	16 of subsection (c-7) of Section 1-75 of the Illinois Power
8302	8302	17 Agency Act and this subsection (i-7). The electric utility's
8303	8303	18 tariff shall provide for imposition of the Dispatchable and
8304	8304	19 Reliable Renewable Energy Charge on a per-kilowatthour basis
8305	8305	20 to all kilowatthours delivered by the electric utility to its
8306	8306	21 delivery services customers. The tariff shall provide for the
8307	8307	22 calculation of the dispatchable and reliable renewable energy
8308	8308	23 charge to be in effect for the year beginning January 1, 2025
8309	8309	24 and each year beginning January 1 thereafter, sufficient to
8310	8310	25 collect the electric utility's estimated payment obligations
8311	8311	26 for the delivery year beginning the following June 1 under
8312	8312
8313	8313
8314	8314
8315	8315
8316	8316
8317	8317	HB5514 - 230 - LRB103 39335 CES 69496 b
8318	8318
8319	8319
8320	8320	HB5514- 231 -LRB103 39335 CES 69496 b HB5514 - 231 - LRB103 39335 CES 69496 b
8321	8321	HB5514 - 231 - LRB103 39335 CES 69496 b
8322	8322	1 contracts for purchase of high voltage direct current
8323	8323	2 renewable energy credits entered into pursuant to subsection
8324	8324	3 (c-7) of Section 1-75 of the Illinois Power Agency Act. The
8325	8325	4 tariff shall provide that any excess or shortfall of
8326	8326	5 collections to payments shall be deducted from or added to, on
8327	8327	6 a per-kilowatthour basis, the dispatchable and reliable
8328	8328	7 renewable energy charge, over the 6-month period beginning
8329	8329	8 October 1 of that calendar year.
8330	8330	9 (j) If a retail customer that obtains electric power and
8331	8331	10 energy from cogeneration or self-generation facilities
8332	8332	11 installed for its own use on or before January 1, 1997,
8333	8333	12 subsequently takes service from an alternative retail electric
8334	8334	13 supplier or an electric utility other than the electric
8335	8335	14 utility in whose service area the customer is located for any
8336	8336	15 portion of the customer's electric power and energy
8337	8337	16 requirements formerly obtained from those facilities
8338	8338	17 (including that amount purchased from the utility in lieu of
8339	8339	18 such generation and not as standby power purchases, under a
8340	8340	19 cogeneration displacement tariff in effect as of the effective
8341	8341	20 date of this amendatory Act of 1997), the transition charges
8342	8342	21 otherwise applicable pursuant to subsections (f), (g), or (h)
8343	8343	22 of this Section shall not be applicable in any year to that
8344	8344	23 portion of the customer's electric power and energy
8345	8345	24 requirements formerly obtained from those facilities,
8346	8346	25 provided, that for purposes of this subsection (j), such
8347	8347	26 portion shall not exceed the average number of kilowatt-hours
8348	8348
8349	8349
8350	8350
8351	8351
8352	8352
8353	8353	HB5514 - 231 - LRB103 39335 CES 69496 b
8354	8354
8355	8355
8356	8356	HB5514- 232 -LRB103 39335 CES 69496 b HB5514 - 232 - LRB103 39335 CES 69496 b
8357	8357	HB5514 - 232 - LRB103 39335 CES 69496 b
8358	8358	1 per year obtained from the cogeneration or self-generation
8359	8359	2 facilities during the 3 years prior to the date on which the
8360	8360	3 customer became eligible for delivery services, except as
8361	8361	4 provided in subsection (f) of Section 16-110.
8362	8362	5 (k) The electric utility shall be entitled to recover
8363	8363	6 through tariffed charges all of the costs associated with the
8364	8364	7 purchase of zero emission credits from zero emission
8365	8365	8 facilities to meet the requirements of subsection (d-5) of
8366	8366	9 Section 1-75 of the Illinois Power Agency Act and all of the
8367	8367	10 costs associated with the purchase of carbon mitigation
8368	8368	11 credits from carbon-free energy resources to meet the
8369	8369	12 requirements of subsection (d-10) of Section 1-75 of the
8370	8370	13 Illinois Power Agency Act. Such costs shall include the costs
8371	8371	14 of procuring the zero emission credits and carbon mitigation
8372	8372	15 credits from carbon-free energy resources, as well as the
8373	8373	16 reasonable costs that the utility incurs as part of the
8374	8374	17 procurement processes and to implement and comply with plans
8375	8375	18 and processes approved by the Commission under subsections
8376	8376	19 (d-5) and (d-10). The costs shall be allocated across all
8377	8377	20 retail customers through a single, uniform cents per
8378	8378	21 kilowatt-hour charge applicable to all retail customers, which
8379	8379	22 shall appear as a separate line item on each customer's bill.
8380	8380	23 Beginning June 1, 2017, the electric utility shall be entitled
8381	8381	24 to recover through tariffed charges all of the costs
8382	8382	25 associated with the purchase of renewable energy resources to
8383	8383	26 meet the renewable energy resource standards of subsection (c)
8384	8384
8385	8385
8386	8386
8387	8387
8388	8388
8389	8389	HB5514 - 232 - LRB103 39335 CES 69496 b
8390	8390
8391	8391
8392	8392	HB5514- 233 -LRB103 39335 CES 69496 b HB5514 - 233 - LRB103 39335 CES 69496 b
8393	8393	HB5514 - 233 - LRB103 39335 CES 69496 b
8394	8394	1 of Section 1-75 of the Illinois Power Agency Act, under
8395	8395	2 procurement plans as approved in accordance with that Section
8396	8396	3 and Section 16-111.5 of this Act. Such costs shall include the
8397	8397	4 costs of procuring the renewable energy resources, as well as
8398	8398	5 the reasonable costs that the utility incurs as part of the
8399	8399	6 procurement processes and to implement and comply with plans
8400	8400	7 and processes approved by the Commission under such Sections.
8401	8401	8 The costs associated with the purchase of renewable energy
8402	8402	9 resources shall be allocated across all retail customers in
8403	8403	10 proportion to the amount of renewable energy resources the
8404	8404	11 utility procures for such customers through a single, uniform
8405	8405	12 cents per kilowatt-hour charge applicable to such retail
8406	8406	13 customers, which shall appear as a separate line item on each
8407	8407	14 such customer's bill. The credits, costs, and penalties
8408	8408	15 associated with the self-direct renewable portfolio standard
8409	8409	16 compliance program described in subparagraph (R) of paragraph
8410	8410	17 (1) of subsection (c) of Section 1-75 of the Illinois Power
8411	8411	18 Agency Act shall be allocated to approved eligible self-direct
8412	8412	19 customers by the utility in a cents per kilowatt-hour credit,
8413	8413	20 cost, or penalty, which shall appear as a separate line item on
8414	8414	21 each such customer's bill.
8415	8415	22 Notwithstanding whether the Commission has approved the
8416	8416	23 initial long-term renewable resources procurement plan as of
8417	8417	24 June 1, 2017, an electric utility shall place new tariffed
8418	8418	25 charges into effect beginning with the June 2017 monthly
8419	8419	26 billing period, to the extent practicable, to begin recovering
8420	8420
8421	8421
8422	8422
8423	8423
8424	8424
8425	8425	HB5514 - 233 - LRB103 39335 CES 69496 b
8426	8426
8427	8427
8428	8428	HB5514- 234 -LRB103 39335 CES 69496 b HB5514 - 234 - LRB103 39335 CES 69496 b
8429	8429	HB5514 - 234 - LRB103 39335 CES 69496 b
8430	8430	1 the costs of procuring renewable energy resources, as those
8431	8431	2 charges are calculated under the limitations described in
8432	8432	3 subparagraph (E) of paragraph (1) of subsection (c) of Section
8433	8433	4 1-75 of the Illinois Power Agency Act. Notwithstanding the
8434	8434	5 date on which the utility places such new tariffed charges
8435	8435	6 into effect, the utility shall be permitted to collect the
8436	8436	7 charges under such tariff as if the tariff had been in effect
8437	8437	8 beginning with the first day of the June 2017 monthly billing
8438	8438	9 period. For the delivery years commencing June 1, 2017, June
8439	8439	10 1, 2018, June 1, 2019, and each delivery year thereafter, the
8440	8440	11 electric utility shall deposit into a separate interest
8441	8441	12 bearing account of a financial institution the monies
8442	8442	13 collected under the tariffed charges. Money collected from
8443	8443	14 customers for the procurement of renewable energy resources in
8444	8444	15 a given delivery year may be spent by the utility for the
8445	8445	16 procurement of renewable resources over any of the following 5
8446	8446	17 delivery years, after which unspent money shall be credited
8447	8447	18 back to retail customers. The electric utility shall spend all
8448	8448	19 money collected in earlier delivery years that has not yet
8449	8449	20 been returned to customers, first, before spending money
8450	8450	21 collected in later delivery years. Any interest earned shall
8451	8451	22 be credited back to retail customers under the reconciliation
8452	8452	23 proceeding provided for in this subsection (k), provided that
8453	8453	24 the electric utility shall first be reimbursed from the
8454	8454	25 interest for the administrative costs that it incurs to
8455	8455	26 administer and manage the account. Any taxes due on the funds
8456	8456
8457	8457
8458	8458
8459	8459
8460	8460
8461	8461	HB5514 - 234 - LRB103 39335 CES 69496 b
8462	8462
8463	8463
8464	8464	HB5514- 235 -LRB103 39335 CES 69496 b HB5514 - 235 - LRB103 39335 CES 69496 b
8465	8465	HB5514 - 235 - LRB103 39335 CES 69496 b
8466	8466	1 in the account, or interest earned on it, will be paid from the
8467	8467	2 account or, if insufficient monies are available in the
8468	8468	3 account, from the monies collected under the tariffed charges
8469	8469	4 to recover the costs of procuring renewable energy resources.
8470	8470	5 Monies deposited in the account shall be subject to the
8471	8471	6 review, reconciliation, and true-up process described in this
8472	8472	7 subsection (k) that is applicable to the funds collected and
8473	8473	8 costs incurred for the procurement of renewable energy
8474	8474	9 resources.
8475	8475	10 The electric utility shall be entitled to recover all of
8476	8476	11 the costs identified in this subsection (k) through automatic
8477	8477	12 adjustment clause tariffs applicable to all of the utility's
8478	8478	13 retail customers that allow the electric utility to adjust its
8479	8479	14 tariffed charges consistent with this subsection (k). The
8480	8480	15 determination as to whether any excess funds were collected
8481	8481	16 during a given delivery year for the purchase of renewable
8482	8482	17 energy resources, and the crediting of any excess funds back
8483	8483	18 to retail customers, shall not be made until after the close of
8484	8484	19 the delivery year, which will ensure that the maximum amount
8485	8485	20 of funds is available to implement the approved long-term
8486	8486	21 renewable resources procurement plan during a given delivery
8487	8487	22 year. The amount of excess funds eligible to be credited back
8488	8488	23 to retail customers shall be reduced by an amount equal to the
8489	8489	24 payment obligations required by any contracts entered into by
8490	8490	25 an electric utility under contracts described in subsection
8491	8491	26 (b) of Section 1-56 and subsection (c) of Section 1-75 of the
8492	8492
8493	8493
8494	8494
8495	8495
8496	8496
8497	8497	HB5514 - 235 - LRB103 39335 CES 69496 b
8498	8498
8499	8499
8500	8500	HB5514- 236 -LRB103 39335 CES 69496 b HB5514 - 236 - LRB103 39335 CES 69496 b
8501	8501	HB5514 - 236 - LRB103 39335 CES 69496 b
8502	8502	1 Illinois Power Agency Act, even if such payments have not yet
8503	8503	2 been made and regardless of the delivery year in which those
8504	8504	3 payment obligations were incurred. Notwithstanding anything to
8505	8505	4 the contrary, including in tariffs authorized by this
8506	8506	5 subsection (k) in effect before the effective date of this
8507	8507	6 amendatory Act of the 102nd General Assembly, all unspent
8508	8508	7 funds as of May 31, 2021, excluding any funds credited to
8509	8509	8 customers during any utility billing cycle that commences
8510	8510	9 prior to the effective date of this amendatory Act of the 102nd
8511	8511	10 General Assembly, shall remain in the utility account and
8512	8512	11 shall on a first in, first out basis be used toward utility
8513	8513	12 payment obligations under contracts described in subsection
8514	8514	13 (b) of Section 1-56 and subsection (c) of Section 1-75 of the
8515	8515	14 Illinois Power Agency Act. The electric utility's collections
8516	8516	15 under such automatic adjustment clause tariffs to recover the
8517	8517	16 costs of renewable energy resources, zero emission credits
8518	8518	17 from zero emission facilities, and carbon mitigation credits
8519	8519	18 from carbon-free energy resources shall be subject to separate
8520	8520	19 annual review, reconciliation, and true-up against actual
8521	8521	20 costs by the Commission under a procedure that shall be
8522	8522	21 specified in the electric utility's automatic adjustment
8523	8523	22 clause tariffs and that shall be approved by the Commission in
8524	8524	23 connection with its approval of such tariffs. The procedure
8525	8525	24 shall provide that any difference between the electric
8526	8526	25 utility's collections for zero emission credits and carbon
8527	8527	26 mitigation credits under the automatic adjustment charges for
8528	8528
8529	8529
8530	8530
8531	8531
8532	8532
8533	8533	HB5514 - 236 - LRB103 39335 CES 69496 b
8534	8534
8535	8535
8536	8536	HB5514- 237 -LRB103 39335 CES 69496 b HB5514 - 237 - LRB103 39335 CES 69496 b
8537	8537	HB5514 - 237 - LRB103 39335 CES 69496 b
8538	8538	1 an annual period and the electric utility's actual costs of
8539	8539	2 zero emission credits from zero emission facilities and carbon
8540	8540	3 mitigation credits from carbon-free energy resources for that
8541	8541	4 same annual period shall be refunded to or collected from, as
8542	8542	5 applicable, the electric utility's retail customers in
8543	8543	6 subsequent periods.
8544	8544	7 Nothing in this subsection (k) is intended to affect,
8545	8545	8 limit, or change the right of the electric utility to recover
8546	8546	9 the costs associated with the procurement of renewable energy
8547	8547	10 resources for periods commencing before, on, or after June 1,
8548	8548	11 2017, as otherwise provided in the Illinois Power Agency Act.
8549	8549	12 The funding available under this subsection (k), if any,
8550	8550	13 for the programs described under subsection (b) of Section
8551	8551	14 1-56 of the Illinois Power Agency Act shall not reduce the
8552	8552	15 amount of funding for the programs described in subparagraph
8553	8553	16 (O) of paragraph (1) of subsection (c) of Section 1-75 of the
8554	8554	17 Illinois Power Agency Act. If funding is available under this
8555	8555	18 subsection (k) for programs described under subsection (b) of
8556	8556	19 Section 1-56 of the Illinois Power Agency Act, then the
8557	8557	20 long-term renewable resources plan shall provide for the
8558	8558	21 Agency to procure contracts in an amount that does not exceed
8559	8559	22 the funding, and the contracts approved by the Commission
8560	8560	23 shall be executed by the applicable utility or utilities.
8561	8561	24 (l) A utility that has terminated any contract executed
8562	8562	25 under subsection (d-5) or (d-10) of Section 1-75 of the
8563	8563	26 Illinois Power Agency Act shall be entitled to recover any
8564	8564
8565	8565
8566	8566
8567	8567
8568	8568
8569	8569	HB5514 - 237 - LRB103 39335 CES 69496 b
8570	8570
8571	8571
8572	8572	HB5514- 238 -LRB103 39335 CES 69496 b HB5514 - 238 - LRB103 39335 CES 69496 b
8573	8573	HB5514 - 238 - LRB103 39335 CES 69496 b
8574	8574	1 remaining balance associated with the purchase of zero
8575	8575	2 emission credits prior to such termination, and such utility
8576	8576	3 shall also apply a credit to its retail customer bills in the
8577	8577	4 event of any over-collection.
8578	8578	5 (m)(1) An electric utility that recovers its costs of
8579	8579	6 procuring zero emission credits from zero emission facilities
8580	8580	7 through a cents-per-kilowatthour charge under subsection (k)
8581	8581	8 of this Section shall be subject to the requirements of this
8582	8582	9 subsection (m). Notwithstanding anything to the contrary, such
8583	8583	10 electric utility shall, beginning on April 30, 2018, and each
8584	8584	11 April 30 thereafter until April 30, 2026, calculate whether
8585	8585	12 any reduction must be applied to such cents-per-kilowatthour
8586	8586	13 charge that is paid by retail customers of the electric
8587	8587	14 utility that have opted out of subsections (a) through (j) of
8588	8588	15 Section 8-103B of this Act under subsection (l) of Section
8589	8589	16 8-103B. Such charge shall be reduced for such customers for
8590	8590	17 the next delivery year commencing on June 1 based on the amount
8591	8591	18 necessary, if any, to limit the annual estimated average net
8592	8592	19 increase for the prior calendar year due to the future energy
8593	8593	20 investment costs to no more than 1.3% of 5.98 cents per
8594	8594	21 kilowatt-hour, which is the average amount paid per
8595	8595	22 kilowatthour for electric service during the year ending
8596	8596	23 December 31, 2015 by Illinois industrial retail customers, as
8597	8597	24 reported to the Edison Electric Institute.
8598	8598	25 The calculations required by this subsection (m) shall be
8599	8599	26 made only once for each year, and no subsequent rate impact
8600	8600
8601	8601
8602	8602
8603	8603
8604	8604
8605	8605	HB5514 - 238 - LRB103 39335 CES 69496 b
8606	8606
8607	8607
8608	8608	HB5514- 239 -LRB103 39335 CES 69496 b HB5514 - 239 - LRB103 39335 CES 69496 b
8609	8609	HB5514 - 239 - LRB103 39335 CES 69496 b
8610	8610	1 determinations shall be made.
8611	8611	2 (2) For purposes of this Section, "future energy
8612	8612	3 investment costs" shall be calculated by subtracting the
8613	8613	4 cents-per-kilowatthour charge identified in subparagraph (A)
8614	8614	5 of this paragraph (2) from the sum of the
8615	8615	6 cents-per-kilowatthour charges identified in subparagraph (B)
8616	8616	7 of this paragraph (2):
8617	8617	8 (A) The cents-per-kilowatthour charge identified in
8618	8618	9 the electric utility's tariff placed into effect under
8619	8619	10 Section 8-103 of the Public Utilities Act that, on
8620	8620	11 December 1, 2016, was applicable to those retail customers
8621	8621	12 that have opted out of subsections (a) through (j) of
8622	8622	13 Section 8-103B of this Act under subsection (l) of Section
8623	8623	14 8-103B.
8624	8624	15 (B) The sum of the following cents-per-kilowatthour
8625	8625	16 charges applicable to those retail customers that have
8626	8626	17 opted out of subsections (a) through (j) of Section 8-103B
8627	8627	18 of this Act under subsection (l) of Section 8-103B,
8628	8628	19 provided that if one or more of the following charges has
8629	8629	20 been in effect and applied to such customers for more than
8630	8630	21 one calendar year, then each charge shall be equal to the
8631	8631	22 average of the charges applied over a period that
8632	8632	23 commences with the calendar year ending December 31, 2017
8633	8633	24 and ends with the most recently completed calendar year
8634	8634	25 prior to the calculation required by this subsection (m):
8635	8635	26 (i) the cents-per-kilowatthour charge to recover
8636	8636
8637	8637
8638	8638
8639	8639
8640	8640
8641	8641	HB5514 - 239 - LRB103 39335 CES 69496 b
8642	8642
8643	8643
8644	8644	HB5514- 240 -LRB103 39335 CES 69496 b HB5514 - 240 - LRB103 39335 CES 69496 b
8645	8645	HB5514 - 240 - LRB103 39335 CES 69496 b
8646	8646	1 the costs incurred by the utility under subsection
8647	8647	2 (d-5) of Section 1-75 of the Illinois Power Agency
8648	8648	3 Act, adjusted for any reductions required under this
8649	8649	4 subsection (m); and
8650	8650	5 (ii) the cents-per-kilowatthour charge to recover
8651	8651	6 the costs incurred by the utility under Section
8652	8652	7 16-107.6 of the Public Utilities Act.
8653	8653	8 If no charge was applied for a given calendar year
8654	8654	9 under item (i) or (ii) of this subparagraph (B), then the
8655	8655	10 value of the charge for that year shall be zero.
8656	8656	11 (3) If a reduction is required by the calculation
8657	8657	12 performed under this subsection (m), then the amount of the
8658	8658	13 reduction shall be multiplied by the number of years reflected
8659	8659	14 in the averages calculated under subparagraph (B) of paragraph
8660	8660	15 (2) of this subsection (m). Such reduction shall be applied to
8661	8661	16 the cents-per-kilowatthour charge that is applicable to those
8662	8662	17 retail customers that have opted out of subsections (a)
8663	8663	18 through (j) of Section 8-103B of this Act under subsection (l)
8664	8664	19 of Section 8-103B beginning with the next delivery year
8665	8665	20 commencing after the date of the calculation required by this
8666	8666	21 subsection (m).
8667	8667	22 (4) The electric utility shall file a notice with the
8668	8668	23 Commission on May 1 of 2018 and each May 1 thereafter until May
8669	8669	24 1, 2026 containing the reduction, if any, which must be
8670	8670	25 applied for the delivery year which begins in the year of the
8671	8671	26 filing. The notice shall contain the calculations made
8672	8672
8673	8673
8674	8674
8675	8675
8676	8676
8677	8677	HB5514 - 240 - LRB103 39335 CES 69496 b
8678	8678
8679	8679
8680	8680	HB5514- 241 -LRB103 39335 CES 69496 b HB5514 - 241 - LRB103 39335 CES 69496 b
8681	8681	HB5514 - 241 - LRB103 39335 CES 69496 b
8682	8682	1 pursuant to this Section. By October 1 of each year beginning
8683	8683	2 in 2018, each electric utility shall notify the Commission if
8684	8684	3 it appears, based on an estimate of the calculation required
8685	8685	4 in this subsection (m), that a reduction will be required in
8686	8686	5 the next year.
8687	8687	6 (Source: P.A. 102-662, eff. 9-15-21.)
8688	8688	7 (220 ILCS 5/16-111.5)
8689	8689	8 Sec. 16-111.5. Provisions relating to procurement.
8690	8690	9 (a) An electric utility that on December 31, 2005 served
8691	8691	10 at least 100,000 customers in Illinois shall procure power and
8692	8692	11 energy for its eligible retail customers in accordance with
8693	8693	12 the applicable provisions set forth in Section 1-75 of the
8694	8694	13 Illinois Power Agency Act and this Section. Beginning with the
8695	8695	14 delivery year commencing on June 1, 2017, such electric
8696	8696	15 utility shall also procure zero emission credits from zero
8697	8697	16 emission facilities in accordance with the applicable
8698	8698	17 provisions set forth in Section 1-75 of the Illinois Power
8699	8699	18 Agency Act, and, for years beginning on or after June 1, 2017,
8700	8700	19 the utility shall procure renewable energy resources in
8701	8701	20 accordance with the applicable provisions set forth in Section
8702	8702	21 1-75 of the Illinois Power Agency Act and this Section.
8703	8703	22 Beginning with the delivery year commencing on June 1, 2022,
8704	8704	23 an electric utility serving over 3,000,000 customers shall
8705	8705	24 also procure carbon mitigation credits from carbon-free energy
8706	8706	25 resources in accordance with the applicable provisions set
8707	8707
8708	8708
8709	8709
8710	8710
8711	8711
8712	8712	HB5514 - 241 - LRB103 39335 CES 69496 b
8713	8713
8714	8714
8715	8715	HB5514- 242 -LRB103 39335 CES 69496 b HB5514 - 242 - LRB103 39335 CES 69496 b
8716	8716	HB5514 - 242 - LRB103 39335 CES 69496 b
8717	8717	1 forth in Section 1-75 of the Illinois Power Agency Act and this
8718	8718	2 Section. A small multi-jurisdictional electric utility that on
8719	8719	3 December 31, 2005 served less than 100,000 customers in
8720	8720	4 Illinois may elect to procure power and energy for all or a
8721	8721	5 portion of its eligible Illinois retail customers in
8722	8722	6 accordance with the applicable provisions set forth in this
8723	8723	7 Section and Section 1-75 of the Illinois Power Agency Act.
8724	8724	8 This Section shall not apply to a small multi-jurisdictional
8725	8725	9 utility until such time as a small multi-jurisdictional
8726	8726	10 utility requests the Illinois Power Agency to prepare a
8727	8727	11 procurement plan for its eligible retail customers. "Eligible
8728	8728	12 retail customers" for the purposes of this Section means those
8729	8729	13 retail customers that purchase power and energy from the
8730	8730	14 electric utility under fixed-price bundled service tariffs,
8731	8731	15 other than those retail customers whose service is declared or
8732	8732	16 deemed competitive under Section 16-113 and those other
8733	8733	17 customer groups specified in this Section, including
8734	8734	18 self-generating customers, customers electing hourly pricing,
8735	8735	19 or those customers who are otherwise ineligible for
8736	8736	20 fixed-price bundled tariff service. For those customers that
8737	8737	21 are excluded from the procurement plan's electric supply
8738	8738	22 service requirements, and the utility shall procure any supply
8739	8739	23 requirements, including capacity, ancillary services, and
8740	8740	24 hourly priced energy, in the applicable markets as needed to
8741	8741	25 serve those customers, provided that the utility may include
8742	8742	26 in its procurement plan load requirements for the load that is
8743	8743
8744	8744
8745	8745
8746	8746
8747	8747
8748	8748	HB5514 - 242 - LRB103 39335 CES 69496 b
8749	8749
8750	8750
8751	8751	HB5514- 243 -LRB103 39335 CES 69496 b HB5514 - 243 - LRB103 39335 CES 69496 b
8752	8752	HB5514 - 243 - LRB103 39335 CES 69496 b
8753	8753	1 associated with those retail customers whose service has been
8754	8754	2 declared or deemed competitive pursuant to Section 16-113 of
8755	8755	3 this Act to the extent that those customers are purchasing
8756	8756	4 power and energy during one of the transition periods
8757	8757	5 identified in subsection (b) of Section 16-113 of this Act.
8758	8758	6 (b) A procurement plan shall be prepared for each electric
8759	8759	7 utility consistent with the applicable requirements of the
8760	8760	8 Illinois Power Agency Act and this Section. For purposes of
8761	8761	9 this Section, Illinois electric utilities that are affiliated
8762	8762	10 by virtue of a common parent company are considered to be a
8763	8763	11 single electric utility. Small multi-jurisdictional utilities
8764	8764	12 may request a procurement plan for a portion of or all of its
8765	8765	13 Illinois load. Each procurement plan shall analyze the
8766	8766	14 projected balance of supply and demand for those retail
8767	8767	15 customers to be included in the plan's electric supply service
8768	8768	16 requirements over a 5-year period, with the first planning
8769	8769	17 year beginning on June 1 of the year following the year in
8770	8770	18 which the plan is filed. The plan shall specifically identify
8771	8771	19 the wholesale products to be procured following plan approval,
8772	8772	20 and shall follow all the requirements set forth in the Public
8773	8773	21 Utilities Act and all applicable State and federal laws,
8774	8774	22 statutes, rules, or regulations, as well as Commission orders.
8775	8775	23 Nothing in this Section precludes consideration of contracts
8776	8776	24 longer than 5 years and related forecast data. Unless
8777	8777	25 specified otherwise in this Section, in the procurement plan
8778	8778	26 or in the implementing tariff, any procurement occurring in
8779	8779
8780	8780
8781	8781
8782	8782
8783	8783
8784	8784	HB5514 - 243 - LRB103 39335 CES 69496 b
8785	8785
8786	8786
8787	8787	HB5514- 244 -LRB103 39335 CES 69496 b HB5514 - 244 - LRB103 39335 CES 69496 b
8788	8788	HB5514 - 244 - LRB103 39335 CES 69496 b
8789	8789	1 accordance with this plan shall be competitively bid through a
8790	8790	2 request for proposals process. Approval and implementation of
8791	8791	3 the procurement plan shall be subject to review and approval
8792	8792	4 by the Commission according to the provisions set forth in
8793	8793	5 this Section. A procurement plan shall include each of the
8794	8794	6 following components:
8795	8795	7 (1) Hourly load analysis. This analysis shall include:
8796	8796	8 (i) multi-year historical analysis of hourly
8797	8797	9 loads;
8798	8798	10 (ii) switching trends and competitive retail
8799	8799	11 market analysis;
8800	8800	12 (iii) known or projected changes to future loads;
8801	8801	13 and
8802	8802	14 (iv) growth forecasts by customer class.
8803	8803	15 (2) Analysis of the impact of any demand side and
8804	8804	16 renewable energy initiatives. This analysis shall include:
8805	8805	17 (i) the impact of demand response programs and
8806	8806	18 energy efficiency programs, both current and
8807	8807	19 projected; for small multi-jurisdictional utilities,
8808	8808	20 the impact of demand response and energy efficiency
8809	8809	21 programs approved pursuant to Section 8-408 of this
8810	8810	22 Act, both current and projected; and
8811	8811	23 (ii) supply side needs that are projected to be
8812	8812	24 offset by purchases of renewable energy resources, if
8813	8813	25 any.
8814	8814	26 (3) A plan for meeting the expected load requirements
8815	8815
8816	8816
8817	8817
8818	8818
8819	8819
8820	8820	HB5514 - 244 - LRB103 39335 CES 69496 b
8821	8821
8822	8822
8823	8823	HB5514- 245 -LRB103 39335 CES 69496 b HB5514 - 245 - LRB103 39335 CES 69496 b
8824	8824	HB5514 - 245 - LRB103 39335 CES 69496 b
8825	8825	1 that will not be met through preexisting contracts. This
8826	8826	2 plan shall include:
8827	8827	3 (i) definitions of the different Illinois retail
8828	8828	4 customer classes for which supply is being purchased;
8829	8829	5 (ii) the proposed mix of demand-response products
8830	8830	6 for which contracts will be executed during the next
8831	8831	7 year. For small multi-jurisdictional electric
8832	8832	8 utilities that on December 31, 2005 served fewer than
8833	8833	9 100,000 customers in Illinois, these shall be defined
8834	8834	10 as demand-response products offered in an energy
8835	8835	11 efficiency plan approved pursuant to Section 8-408 of
8836	8836	12 this Act. The cost-effective demand-response measures
8837	8837	13 shall be procured whenever the cost is lower than
8838	8838	14 procuring comparable capacity products, provided that
8839	8839	15 such products shall:
8840	8840	16 (A) be procured by a demand-response provider
8841	8841	17 from those retail customers included in the plan's
8842	8842	18 electric supply service requirements;
8843	8843	19 (B) at least satisfy the demand-response
8844	8844	20 requirements of the regional transmission
8845	8845	21 organization market in which the utility's service
8846	8846	22 territory is located, including, but not limited
8847	8847	23 to, any applicable capacity or dispatch
8848	8848	24 requirements;
8849	8849	25 (C) provide for customers' participation in
8850	8850	26 the stream of benefits produced by the
8851	8851
8852	8852
8853	8853
8854	8854
8855	8855
8856	8856	HB5514 - 245 - LRB103 39335 CES 69496 b
8857	8857
8858	8858
8859	8859	HB5514- 246 -LRB103 39335 CES 69496 b HB5514 - 246 - LRB103 39335 CES 69496 b
8860	8860	HB5514 - 246 - LRB103 39335 CES 69496 b
8861	8861	1 demand-response products;
8862	8862	2 (D) provide for reimbursement by the
8863	8863	3 demand-response provider of the utility for any
8864	8864	4 costs incurred as a result of the failure of the
8865	8865	5 supplier of such products to perform its
8866	8866	6 obligations thereunder; and
8867	8867	7 (E) meet the same credit requirements as apply
8868	8868	8 to suppliers of capacity, in the applicable
8869	8869	9 regional transmission organization market;
8870	8870	10 (iii) monthly forecasted system supply
8871	8871	11 requirements, including expected minimum, maximum, and
8872	8872	12 average values for the planning period;
8873	8873	13 (iv) the proposed mix and selection of standard
8874	8874	14 wholesale products for which contracts will be
8875	8875	15 executed during the next year, separately or in
8876	8876	16 combination, to meet that portion of its load
8877	8877	17 requirements not met through pre-existing contracts,
8878	8878	18 including but not limited to monthly 5 x 16 peak period
8879	8879	19 block energy, monthly off-peak wrap energy, monthly 7
8880	8880	20 x 24 energy, annual 5 x 16 energy, other standardized
8881	8881	21 energy or capacity products designed to provide
8882	8882	22 eligible retail customer benefits from commercially
8883	8883	23 deployed advanced technologies including but not
8884	8884	24 limited to high voltage direct current converter
8885	8885	25 stations, as such term is defined in Section 1-10 of
8886	8886	26 the Illinois Power Agency Act, whether or not such
8887	8887
8888	8888
8889	8889
8890	8890
8891	8891
8892	8892	HB5514 - 246 - LRB103 39335 CES 69496 b
8893	8893
8894	8894
8895	8895	HB5514- 247 -LRB103 39335 CES 69496 b HB5514 - 247 - LRB103 39335 CES 69496 b
8896	8896	HB5514 - 247 - LRB103 39335 CES 69496 b
8897	8897	1 product is currently available in wholesale markets,
8898	8898	2 annual off-peak wrap energy, annual 7 x 24 energy,
8899	8899	3 monthly capacity, annual capacity, peak load capacity
8900	8900	4 obligations, capacity purchase plan, and ancillary
8901	8901	5 services;
8902	8902	6 (v) proposed term structures for each wholesale
8903	8903	7 product type included in the proposed procurement plan
8904	8904	8 portfolio of products; and
8905	8905	9 (vi) an assessment of the price risk, load
8906	8906	10 uncertainty, and other factors that are associated
8907	8907	11 with the proposed procurement plan; this assessment,
8908	8908	12 to the extent possible, shall include an analysis of
8909	8909	13 the following factors: contract terms, time frames for
8910	8910	14 securing products or services, fuel costs, weather
8911	8911	15 patterns, transmission costs, market conditions, and
8912	8912	16 the governmental regulatory environment; the proposed
8913	8913	17 procurement plan shall also identify alternatives for
8914	8914	18 those portfolio measures that are identified as having
8915	8915	19 significant price risk and mitigation in the form of
8916	8916	20 additional retail customer and ratepayer price,
8917	8917	21 reliability, and environmental benefits from
8918	8918	22 standardized energy products delivered from
8919	8919	23 commercially deployed advanced technologies,
8920	8920	24 including, but not limited to, high voltage direct
8921	8921	25 current converter stations, as such term is defined in
8922	8922	26 Section 1-10 of the Illinois Power Agency Act, whether
8923	8923
8924	8924
8925	8925
8926	8926
8927	8927
8928	8928	HB5514 - 247 - LRB103 39335 CES 69496 b
8929	8929
8930	8930
8931	8931	HB5514- 248 -LRB103 39335 CES 69496 b HB5514 - 248 - LRB103 39335 CES 69496 b
8932	8932	HB5514 - 248 - LRB103 39335 CES 69496 b
8933	8933	1 or not such product is currently available in
8934	8934	2 wholesale markets.
8935	8935	3 (4) Proposed procedures for balancing loads. The
8936	8936	4 procurement plan shall include, for load requirements
8937	8937	5 included in the procurement plan, the process for (i)
8938	8938	6 hourly balancing of supply and demand and (ii) the
8939	8939	7 criteria for portfolio re-balancing in the event of
8940	8940	8 significant shifts in load.
8941	8941	9 (5) Long-Term Renewable Resources Procurement Plan.
8942	8942	10 The Agency shall prepare a long-term renewable resources
8943	8943	11 procurement plan for the procurement of renewable energy
8944	8944	12 credits under Sections 1-56 and 1-75 of the Illinois Power
8945	8945	13 Agency Act for delivery beginning in the 2017 delivery
8946	8946	14 year.
8947	8947	15 (i) The initial long-term renewable resources
8948	8948	16 procurement plan and all subsequent revisions shall be
8949	8949	17 subject to review and approval by the Commission. For
8950	8950	18 the purposes of this Section, "delivery year" has the
8951	8951	19 same meaning as in Section 1-10 of the Illinois Power
8952	8952	20 Agency Act. For purposes of this Section, "Agency"
8953	8953	21 shall mean the Illinois Power Agency.
8954	8954	22 (ii) The long-term renewable resources planning
8955	8955	23 process shall be conducted as follows:
8956	8956	24 (A) Electric utilities shall provide a range
8957	8957	25 of load forecasts to the Illinois Power Agency
8958	8958	26 within 45 days of the Agency's request for
8959	8959
8960	8960
8961	8961
8962	8962
8963	8963
8964	8964	HB5514 - 248 - LRB103 39335 CES 69496 b
8965	8965
8966	8966
8967	8967	HB5514- 249 -LRB103 39335 CES 69496 b HB5514 - 249 - LRB103 39335 CES 69496 b
8968	8968	HB5514 - 249 - LRB103 39335 CES 69496 b
8969	8969	1 forecasts, which request shall specify the length
8970	8970	2 and conditions for the forecasts including, but
8971	8971	3 not limited to, the quantity of distributed
8972	8972	4 generation expected to be interconnected for each
8973	8973	5 year.
8974	8974	6 (B) The Agency shall publish for comment the
8975	8975	7 initial long-term renewable resources procurement
8976	8976	8 plan no later than 120 days after the effective
8977	8977	9 date of this amendatory Act of the 99th General
8978	8978	10 Assembly and shall review, and may revise, the
8979	8979	11 plan at least every 2 years thereafter. To the
8980	8980	12 extent practicable, the Agency shall review and
8981	8981	13 propose any revisions to the long-term renewable
8982	8982	14 energy resources procurement plan in conjunction
8983	8983	15 with the Agency's other planning and approval
8984	8984	16 processes conducted under this Section. The
8985	8985	17 initial long-term renewable resources procurement
8986	8986	18 plan shall:
8987	8987	19 (aa) Identify the procurement programs and
8988	8988	20 competitive procurement events consistent with
8989	8989	21 the applicable requirements of the Illinois
8990	8990	22 Power Agency Act and shall be designed to
8991	8991	23 achieve the goals set forth in subsection (c)
8992	8992	24 of Section 1-75 of that Act.
8993	8993	25 (bb) Include a schedule for procurements
8994	8994	26 for renewable energy credits from
8995	8995
8996	8996
8997	8997
8998	8998
8999	8999
9000	9000	HB5514 - 249 - LRB103 39335 CES 69496 b
9001	9001
9002	9002
9003	9003	HB5514- 250 -LRB103 39335 CES 69496 b HB5514 - 250 - LRB103 39335 CES 69496 b
9004	9004	HB5514 - 250 - LRB103 39335 CES 69496 b
9005	9005	1 utility-scale wind projects, utility-scale
9006	9006	2 solar projects, and brownfield site
9007	9007	3 photovoltaic projects consistent with
9008	9008	4 subparagraph (G) of paragraph (1) of
9009	9009	5 subsection (c) of Section 1-75 of the Illinois
9010	9010	6 Power Agency Act.
9011	9011	7 (cc) Identify the process whereby the
9012	9012	8 Agency will submit to the Commission for
9013	9013	9 review and approval the proposed contracts to
9014	9014	10 implement the programs required by such plan.
9015	9015	11 Copies of the initial long-term renewable
9016	9016	12 resources procurement plan and all subsequent
9017	9017	13 revisions shall be posted and made publicly
9018	9018	14 available on the Agency's and Commission's
9019	9019	15 websites, and copies shall also be provided to
9020	9020	16 each affected electric utility. An affected
9021	9021	17 utility and other interested parties shall have 45
9022	9022	18 days following the date of posting to provide
9023	9023	19 comment to the Agency on the initial long-term
9024	9024	20 renewable resources procurement plan and all
9025	9025	21 subsequent revisions. All comments submitted to
9026	9026	22 the Agency shall be specific, supported by data or
9027	9027	23 other detailed analyses, and, if objecting to all
9028	9028	24 or a portion of the procurement plan, accompanied
9029	9029	25 by specific alternative wording or proposals. All
9030	9030	26 comments shall be posted on the Agency's and
9031	9031
9032	9032
9033	9033
9034	9034
9035	9035
9036	9036	HB5514 - 250 - LRB103 39335 CES 69496 b
9037	9037
9038	9038
9039	9039	HB5514- 251 -LRB103 39335 CES 69496 b HB5514 - 251 - LRB103 39335 CES 69496 b
9040	9040	HB5514 - 251 - LRB103 39335 CES 69496 b
9041	9041	1 Commission's websites. During this 45-day comment
9042	9042	2 period, the Agency shall hold at least one public
9043	9043	3 hearing within each utility's service area that is
9044	9044	4 subject to the requirements of this paragraph (5)
9045	9045	5 for the purpose of receiving public comment.
9046	9046	6 Within 21 days following the end of the 45-day
9047	9047	7 review period, the Agency may revise the long-term
9048	9048	8 renewable resources procurement plan based on the
9049	9049	9 comments received and shall file the plan with the
9050	9050	10 Commission for review and approval.
9051	9051	11 (C) Within 14 days after the filing of the
9052	9052	12 initial long-term renewable resources procurement
9053	9053	13 plan or any subsequent revisions, any person
9054	9054	14 objecting to the plan may file an objection with
9055	9055	15 the Commission. Within 21 days after the filing of
9056	9056	16 the plan, the Commission shall determine whether a
9057	9057	17 hearing is necessary. The Commission shall enter
9058	9058	18 its order confirming or modifying the initial
9059	9059	19 long-term renewable resources procurement plan or
9060	9060	20 any subsequent revisions within 120 days after the
9061	9061	21 filing of the plan by the Illinois Power Agency.
9062	9062	22 (D) The Commission shall approve the initial
9063	9063	23 long-term renewable resources procurement plan and
9064	9064	24 any subsequent revisions, including expressly the
9065	9065	25 forecast used in the plan and taking into account
9066	9066	26 that funding will be limited to the amount of
9067	9067
9068	9068
9069	9069
9070	9070
9071	9071
9072	9072	HB5514 - 251 - LRB103 39335 CES 69496 b
9073	9073
9074	9074
9075	9075	HB5514- 252 -LRB103 39335 CES 69496 b HB5514 - 252 - LRB103 39335 CES 69496 b
9076	9076	HB5514 - 252 - LRB103 39335 CES 69496 b
9077	9077	1 revenues actually collected by the utilities, if
9078	9078	2 the Commission determines that the plan will
9079	9079	3 reasonably and prudently accomplish the
9080	9080	4 requirements of Section 1-56 and subsection (c) of
9081	9081	5 Section 1-75 of the Illinois Power Agency Act. The
9082	9082	6 Commission shall also approve the process for the
9083	9083	7 submission, review, and approval of the proposed
9084	9084	8 contracts to procure renewable energy credits or
9085	9085	9 implement the programs authorized by the
9086	9086	10 Commission pursuant to a long-term renewable
9087	9087	11 resources procurement plan approved under this
9088	9088	12 Section.
9089	9089	13 In approving any long-term renewable resources
9090	9090	14 procurement plan after the effective date of this
9091	9091	15 amendatory Act of the 102nd General Assembly, the
9092	9092	16 Commission shall approve or modify the Agency's
9093	9093	17 proposal for minimum equity standards pursuant to
9094	9094	18 subsection (c-10) of Section 1-75 of the Illinois
9095	9095	19 Power Agency Act. The Commission shall consider
9096	9096	20 any analysis performed by the Agency in developing
9097	9097	21 its proposal, including past performance,
9098	9098	22 availability of equity eligible contractors, and
9099	9099	23 availability of equity eligible persons at the
9100	9100	24 time the long-term renewable resources procurement
9101	9101	25 plan is approved.
9102	9102	26 (iii) The Agency or third parties contracted by
9103	9103
9104	9104
9105	9105
9106	9106
9107	9107
9108	9108	HB5514 - 252 - LRB103 39335 CES 69496 b
9109	9109
9110	9110
9111	9111	HB5514- 253 -LRB103 39335 CES 69496 b HB5514 - 253 - LRB103 39335 CES 69496 b
9112	9112	HB5514 - 253 - LRB103 39335 CES 69496 b
9113	9113	1 the Agency shall implement all programs authorized by
9114	9114	2 the Commission in an approved long-term renewable
9115	9115	3 resources procurement plan without further review and
9116	9116	4 approval by the Commission. Third parties shall not
9117	9117	5 begin implementing any programs or receive any payment
9118	9118	6 under this Section until the Commission has approved
9119	9119	7 the contract or contracts under the process authorized
9120	9120	8 by the Commission in item (D) of subparagraph (ii) of
9121	9121	9 paragraph (5) of this subsection (b) and the third
9122	9122	10 party and the Agency or utility, as applicable, have
9123	9123	11 executed the contract. For those renewable energy
9124	9124	12 credits subject to procurement through a competitive
9125	9125	13 bid process under the plan or under the initial
9126	9126	14 forward procurements for wind and solar resources
9127	9127	15 described in subparagraph (G) of paragraph (1) of
9128	9128	16 subsection (c) of Section 1-75 of the Illinois Power
9129	9129	17 Agency Act, the Agency shall follow the procurement
9130	9130	18 process specified in the provisions relating to
9131	9131	19 electricity procurement in subsections (e) through (i)
9132	9132	20 of this Section.
9133	9133	21 (iv) An electric utility shall recover its costs
9134	9134	22 associated with the procurement of renewable energy
9135	9135	23 credits under this Section and pursuant to subsection
9136	9136	24 (c-5) and (c-7) of Section 1-75 of the Illinois Power
9137	9137	25 Agency Act through an automatic adjustment clause
9138	9138	26 tariff under subsection (k) or a tariff pursuant to
9139	9139
9140	9140
9141	9141
9142	9142
9143	9143
9144	9144	HB5514 - 253 - LRB103 39335 CES 69496 b
9145	9145
9146	9146
9147	9147	HB5514- 254 -LRB103 39335 CES 69496 b HB5514 - 254 - LRB103 39335 CES 69496 b
9148	9148	HB5514 - 254 - LRB103 39335 CES 69496 b
9149	9149	1 subsection (i-5) or (i-7), as applicable, of Section
9150	9150	2 16-108 of this Act. A utility shall not be required to
9151	9151	3 advance any payment or pay any amounts under this
9152	9152	4 Section that exceed the actual amount of revenues
9153	9153	5 collected by the utility under paragraph (6) of
9154	9154	6 subsection (c) of Section 1-75 of the Illinois Power
9155	9155	7 Agency Act, subsection (c-5) of Section 1-75 of the
9156	9156	8 Illinois Power Agency Act, and subsection (k) or
9157	9157	9 subsection (i-5), as applicable, of Section 16-108 of
9158	9158	10 this Act, and contracts executed under this Section
9159	9159	11 shall expressly incorporate this limitation.
9160	9160	12 (v) For the public interest, safety, and welfare,
9161	9161	13 the Agency and the Commission may adopt rules to carry
9162	9162	14 out the provisions of this Section on an emergency
9163	9163	15 basis immediately following the effective date of this
9164	9164	16 amendatory Act of the 99th General Assembly.
9165	9165	17 (vi) On or before July 1 of each year, the
9166	9166	18 Commission shall hold an informal hearing for the
9167	9167	19 purpose of receiving comments on the prior year's
9168	9168	20 procurement process and any recommendations for
9169	9169	21 change.
9170	9170	22 (b-5) An electric utility that as of January 1, 2019
9171	9171	23 served more than 300,000 retail customers in this State shall
9172	9172	24 purchase renewable energy credits from new renewable energy
9173	9173	25 facilities constructed at or adjacent to the sites of
9174	9174	26 coal-fueled electric generating facilities in this State in
9175	9175
9176	9176
9177	9177
9178	9178
9179	9179
9180	9180	HB5514 - 254 - LRB103 39335 CES 69496 b
9181	9181
9182	9182
9183	9183	HB5514- 255 -LRB103 39335 CES 69496 b HB5514 - 255 - LRB103 39335 CES 69496 b
9184	9184	HB5514 - 255 - LRB103 39335 CES 69496 b
9185	9185	1 accordance with subsection (c-5) of Section 1-75 of the
9186	9186	2 Illinois Power Agency Act. Except as expressly provided in
9187	9187	3 this Section, the plans and procedures for such procurements
9188	9188	4 shall not be included in the procurement plans provided for in
9189	9189	5 this Section, but rather shall be conducted and implemented
9190	9190	6 solely in accordance with subsection (c-5) of Section 1-75 of
9191	9191	7 the Illinois Power Agency Act.
9192	9192	8 (b-7) An electric utility that as of January 1, 2019
9193	9193	9 served more than 300,000 retail customers in this State shall
9194	9194	10 purchase high voltage direct current renewable energy credits
9195	9195	11 in accordance with subsection (c-7) of Section 1-75 of the
9196	9196	12 Illinois Power Agency Act. Except as expressly provided in
9197	9197	13 this Section, the plans and procedures for such procurements
9198	9198	14 shall not be included in the procurement plans provided for in
9199	9199	15 this Section, but rather shall be conducted and implemented
9200	9200	16 solely in accordance with subsection (c-7) of Section 1-75 of
9201	9201	17 the Illinois Power Agency Act.
9202	9202	18 (c) The provisions of this subsection (c) shall not apply
9203	9203	19 to procurements conducted pursuant to subsection (c-5) or
9204	9204	20 (c-7) of Section 1-75 of the Illinois Power Agency Act.
9205	9205	21 However, the Agency may retain a procurement administrator to
9206	9206	22 assist the Agency in planning and carrying out the procurement
9207	9207	23 events and implementing the other requirements specified in
9208	9208	24 such subsection (c-5) of Section 1-75 of the Illinois Power
9209	9209	25 Agency Act, with the costs incurred by the Agency for the
9210	9210	26 procurement administrator to be recovered through fees charged
9211	9211
9212	9212
9213	9213
9214	9214
9215	9215
9216	9216	HB5514 - 255 - LRB103 39335 CES 69496 b
9217	9217
9218	9218
9219	9219	HB5514- 256 -LRB103 39335 CES 69496 b HB5514 - 256 - LRB103 39335 CES 69496 b
9220	9220	HB5514 - 256 - LRB103 39335 CES 69496 b
9221	9221	1 to applicants for selection to sell and deliver renewable
9222	9222	2 energy credits to electric utilities pursuant to subsection
9223	9223	3 (c-5) or (c-7) of Section 1-75 of the Illinois Power Agency
9224	9224	4 Act. The procurement process set forth in Section 1-75 of the
9225	9225	5 Illinois Power Agency Act and subsection (e) of this Section
9226	9226	6 shall be administered by a procurement administrator and
9227	9227	7 monitored by a procurement monitor.
9228	9228	8 (1) The procurement administrator shall:
9229	9229	9 (i) design the final procurement process in
9230	9230	10 accordance with Section 1-75 of the Illinois Power
9231	9231	11 Agency Act and subsection (e) of this Section
9232	9232	12 following Commission approval of the procurement plan;
9233	9233	13 (ii) develop benchmarks in accordance with
9234	9234	14 subsection (e)(3) to be used to evaluate bids; these
9235	9235	15 benchmarks shall be submitted to the Commission for
9236	9236	16 review and approval on a confidential basis prior to
9237	9237	17 the procurement event;
9238	9238	18 (iii) serve as the interface between the electric
9239	9239	19 utility and suppliers;
9240	9240	20 (iv) manage the bidder pre-qualification and
9241	9241	21 registration process;
9242	9242	22 (v) obtain the electric utilities' agreement to
9243	9243	23 the final form of all supply contracts and credit
9244	9244	24 collateral agreements;
9245	9245	25 (vi) administer the request for proposals process;
9246	9246	26 (vii) have the discretion to negotiate to
9247	9247
9248	9248
9249	9249
9250	9250
9251	9251
9252	9252	HB5514 - 256 - LRB103 39335 CES 69496 b
9253	9253
9254	9254
9255	9255	HB5514- 257 -LRB103 39335 CES 69496 b HB5514 - 257 - LRB103 39335 CES 69496 b
9256	9256	HB5514 - 257 - LRB103 39335 CES 69496 b
9257	9257	1 determine whether bidders are willing to lower the
9258	9258	2 price of bids that meet the benchmarks approved by the
9259	9259	3 Commission; any post-bid negotiations with bidders
9260	9260	4 shall be limited to price only and shall be completed
9261	9261	5 within 24 hours after opening the sealed bids and
9262	9262	6 shall be conducted in a fair and unbiased manner; in
9263	9263	7 conducting the negotiations, there shall be no
9264	9264	8 disclosure of any information derived from proposals
9265	9265	9 submitted by competing bidders; if information is
9266	9266	10 disclosed to any bidder, it shall be provided to all
9267	9267	11 competing bidders;
9268	9268	12 (viii) maintain confidentiality of supplier and
9269	9269	13 bidding information in a manner consistent with all
9270	9270	14 applicable laws, rules, regulations, and tariffs;
9271	9271	15 (ix) submit a confidential report to the
9272	9272	16 Commission recommending acceptance or rejection of
9273	9273	17 bids;
9274	9274	18 (x) notify the utility of contract counterparties
9275	9275	19 and contract specifics; and
9276	9276	20 (xi) administer related contingency procurement
9277	9277	21 events.
9278	9278	22 (2) The procurement monitor, who shall be retained by
9279	9279	23 the Commission, shall:
9280	9280	24 (i) monitor interactions among the procurement
9281	9281	25 administrator, suppliers, and utility;
9282	9282	26 (ii) monitor and report to the Commission on the
9283	9283
9284	9284
9285	9285
9286	9286
9287	9287
9288	9288	HB5514 - 257 - LRB103 39335 CES 69496 b
9289	9289
9290	9290
9291	9291	HB5514- 258 -LRB103 39335 CES 69496 b HB5514 - 258 - LRB103 39335 CES 69496 b
9292	9292	HB5514 - 258 - LRB103 39335 CES 69496 b
9293	9293	1 progress of the procurement process;
9294	9294	2 (iii) provide an independent confidential report
9295	9295	3 to the Commission regarding the results of the
9296	9296	4 procurement event;
9297	9297	5 (iv) assess compliance with the procurement plans
9298	9298	6 approved by the Commission for each utility that on
9299	9299	7 December 31, 2005 provided electric service to at
9300	9300	8 least 100,000 customers in Illinois and for each small
9301	9301	9 multi-jurisdictional utility that on December 31, 2005
9302	9302	10 served less than 100,000 customers in Illinois;
9303	9303	11 (v) preserve the confidentiality of supplier and
9304	9304	12 bidding information in a manner consistent with all
9305	9305	13 applicable laws, rules, regulations, and tariffs;
9306	9306	14 (vi) provide expert advice to the Commission and
9307	9307	15 consult with the procurement administrator regarding
9308	9308	16 issues related to procurement process design, rules,
9309	9309	17 protocols, and policy-related matters; and
9310	9310	18 (vii) consult with the procurement administrator
9311	9311	19 regarding the development and use of benchmark
9312	9312	20 criteria, standard form contracts, credit policies,
9313	9313	21 and bid documents.
9314	9314	22 (d) Except as provided in subsection (j), the planning
9315	9315	23 process shall be conducted as follows:
9316	9316	24 (1) Beginning in 2008, each Illinois utility procuring
9317	9317	25 power pursuant to this Section shall annually provide a
9318	9318	26 range of load forecasts to the Illinois Power Agency by
9319	9319
9320	9320
9321	9321
9322	9322
9323	9323
9324	9324	HB5514 - 258 - LRB103 39335 CES 69496 b
9325	9325
9326	9326
9327	9327	HB5514- 259 -LRB103 39335 CES 69496 b HB5514 - 259 - LRB103 39335 CES 69496 b
9328	9328	HB5514 - 259 - LRB103 39335 CES 69496 b
9329	9329	1 July 15 of each year, or such other date as may be required
9330	9330	2 by the Commission or Agency. The load forecasts shall
9331	9331	3 cover the 5-year procurement planning period for the next
9332	9332	4 procurement plan and shall include hourly data
9333	9333	5 representing a high-load, low-load, and expected-load
9334	9334	6 scenario for the load of those retail customers included
9335	9335	7 in the plan's electric supply service requirements. The
9336	9336	8 utility shall provide supporting data and assumptions for
9337	9337	9 each of the scenarios.
9338	9338	10 (2) Beginning in 2008, the Illinois Power Agency shall
9339	9339	11 prepare a procurement plan by August 15th of each year, or
9340	9340	12 such other date as may be required by the Commission. The
9341	9341	13 procurement plan shall identify the portfolio of
9342	9342	14 demand-response and power and energy products to be
9343	9343	15 procured. Cost-effective demand-response measures shall be
9344	9344	16 procured as set forth in item (iii) of subsection (b) of
9345	9345	17 this Section. Copies of the procurement plan shall be
9346	9346	18 posted and made publicly available on the Agency's and
9347	9347	19 Commission's websites, and copies shall also be provided
9348	9348	20 to each affected electric utility. An affected utility
9349	9349	21 shall have 30 days following the date of posting to
9350	9350	22 provide comment to the Agency on the procurement plan.
9351	9351	23 Other interested entities also may comment on the
9352	9352	24 procurement plan. All comments submitted to the Agency
9353	9353	25 shall be specific, supported by data or other detailed
9354	9354	26 analyses, and, if objecting to all or a portion of the
9355	9355
9356	9356
9357	9357
9358	9358
9359	9359
9360	9360	HB5514 - 259 - LRB103 39335 CES 69496 b
9361	9361
9362	9362
9363	9363	HB5514- 260 -LRB103 39335 CES 69496 b HB5514 - 260 - LRB103 39335 CES 69496 b
9364	9364	HB5514 - 260 - LRB103 39335 CES 69496 b
9365	9365	1 procurement plan, accompanied by specific alternative
9366	9366	2 wording or proposals. All comments shall be posted on the
9367	9367	3 Agency's and Commission's websites. During this 30-day
9368	9368	4 comment period, the Agency shall hold at least one public
9369	9369	5 hearing within each utility's service area for the purpose
9370	9370	6 of receiving public comment on the procurement plan.
9371	9371	7 Within 14 days following the end of the 30-day review
9372	9372	8 period, the Agency shall revise the procurement plan as
9373	9373	9 necessary based on the comments received and file the
9374	9374	10 procurement plan with the Commission and post the
9375	9375	11 procurement plan on the websites.
9376	9376	12 (3) Within 5 days after the filing of the procurement
9377	9377	13 plan, any person objecting to the procurement plan shall
9378	9378	14 file an objection with the Commission. Within 10 days
9379	9379	15 after the filing, the Commission shall determine whether a
9380	9380	16 hearing is necessary. The Commission shall enter its order
9381	9381	17 confirming or modifying the procurement plan within 90
9382	9382	18 days after the filing of the procurement plan by the
9383	9383	19 Illinois Power Agency.
9384	9384	20 (4) The Commission shall approve the procurement plan,
9385	9385	21 including expressly the forecast used in the procurement
9386	9386	22 plan, if the Commission determines that it will ensure
9387	9387	23 adequate, reliable, affordable, efficient, and
9388	9388	24 environmentally sustainable electric service at the lowest
9389	9389	25 total cost over time, taking into account any benefits of
9390	9390	26 price stability.
9391	9391
9392	9392
9393	9393
9394	9394
9395	9395
9396	9396	HB5514 - 260 - LRB103 39335 CES 69496 b
9397	9397
9398	9398
9399	9399	HB5514- 261 -LRB103 39335 CES 69496 b HB5514 - 261 - LRB103 39335 CES 69496 b
9400	9400	HB5514 - 261 - LRB103 39335 CES 69496 b
9401	9401	1 (4.5) The Commission shall review the Agency's
9402	9402	2 recommendations for the selection of applicants to enter
9403	9403	3 into long-term contracts for the sale and delivery of
9404	9404	4 renewable energy credits from new renewable energy
9405	9405	5 facilities to be constructed at or adjacent to the sites
9406	9406	6 of coal-fueled electric generating facilities in this
9407	9407	7 State in accordance with the provisions of subsection
9408	9408	8 (c-5) of Section 1-75 of the Illinois Power Agency Act,
9409	9409	9 and shall approve the Agency's recommendations if the
9410	9410	10 Commission determines that the applicants recommended by
9411	9411	11 the Agency for selection, the proposed new renewable
9412	9412	12 energy facilities to be constructed, the amounts of
9413	9413	13 renewable energy credits to be delivered pursuant to the
9414	9414	14 contracts, and the other terms of the contracts, are
9415	9415	15 consistent with the requirements of subsection (c-5) of
9416	9416	16 Section 1-75 of the Illinois Power Agency Act.
9417	9417	17 (e) The procurement process shall include each of the
9418	9418	18 following components:
9419	9419	19 (1) Solicitation, pre-qualification, and registration
9420	9420	20 of bidders. The procurement administrator shall
9421	9421	21 disseminate information to potential bidders to promote a
9422	9422	22 procurement event, notify potential bidders that the
9423	9423	23 procurement administrator may enter into a post-bid price
9424	9424	24 negotiation with bidders that meet the applicable
9425	9425	25 benchmarks, provide supply requirements, and otherwise
9426	9426	26 explain the competitive procurement process. In addition
9427	9427
9428	9428
9429	9429
9430	9430
9431	9431
9432	9432	HB5514 - 261 - LRB103 39335 CES 69496 b
9433	9433
9434	9434
9435	9435	HB5514- 262 -LRB103 39335 CES 69496 b HB5514 - 262 - LRB103 39335 CES 69496 b
9436	9436	HB5514 - 262 - LRB103 39335 CES 69496 b
9437	9437	1 to such other publication as the procurement administrator
9438	9438	2 determines is appropriate, this information shall be
9439	9439	3 posted on the Illinois Power Agency's and the Commission's
9440	9440	4 websites. The procurement administrator shall also
9441	9441	5 administer the prequalification process, including
9442	9442	6 evaluation of credit worthiness, compliance with
9443	9443	7 procurement rules, and agreement to the standard form
9444	9444	8 contract developed pursuant to paragraph (2) of this
9445	9445	9 subsection (e). The procurement administrator shall then
9446	9446	10 identify and register bidders to participate in the
9447	9447	11 procurement event.
9448	9448	12 (2) Standard contract forms and credit terms and
9449	9449	13 instruments. The procurement administrator, in
9450	9450	14 consultation with the utilities, the Commission, and other
9451	9451	15 interested parties and subject to Commission oversight,
9452	9452	16 shall develop and provide standard contract forms for the
9453	9453	17 supplier contracts that meet generally accepted industry
9454	9454	18 practices. Standard credit terms and instruments that meet
9455	9455	19 generally accepted industry practices shall be similarly
9456	9456	20 developed. The procurement administrator shall make
9457	9457	21 available to the Commission all written comments it
9458	9458	22 receives on the contract forms, credit terms, or
9459	9459	23 instruments. If the procurement administrator cannot reach
9460	9460	24 agreement with the applicable electric utility as to the
9461	9461	25 contract terms and conditions, the procurement
9462	9462	26 administrator must notify the Commission of any disputed
9463	9463
9464	9464
9465	9465
9466	9466
9467	9467
9468	9468	HB5514 - 262 - LRB103 39335 CES 69496 b
9469	9469
9470	9470
9471	9471	HB5514- 263 -LRB103 39335 CES 69496 b HB5514 - 263 - LRB103 39335 CES 69496 b
9472	9472	HB5514 - 263 - LRB103 39335 CES 69496 b
9473	9473	1 terms and the Commission shall resolve the dispute. The
9474	9474	2 terms of the contracts shall not be subject to negotiation
9475	9475	3 by winning bidders, and the bidders must agree to the
9476	9476	4 terms of the contract in advance so that winning bids are
9477	9477	5 selected solely on the basis of price.
9478	9478	6 (3) Establishment of a market-based price benchmark.
9479	9479	7 As part of the development of the procurement process, the
9480	9480	8 procurement administrator, in consultation with the
9481	9481	9 Commission staff, Agency staff, and the procurement
9482	9482	10 monitor, shall establish benchmarks for evaluating the
9483	9483	11 final prices in the contracts for each of the products
9484	9484	12 that will be procured through the procurement process. The
9485	9485	13 benchmarks shall be based on price data for similar
9486	9486	14 products for the same delivery period and same delivery
9487	9487	15 hub, or other delivery hubs after adjusting for that
9488	9488	16 difference. The price benchmarks may also be adjusted to
9489	9489	17 take into account differences between the information
9490	9490	18 reflected in the underlying data sources and the specific
9491	9491	19 products and procurement process being used to procure
9492	9492	20 power for the Illinois utilities. The benchmarks shall be
9493	9493	21 confidential but shall be provided to, and will be subject
9494	9494	22 to Commission review and approval, prior to a procurement
9495	9495	23 event.
9496	9496	24 (4) Request for proposals competitive procurement
9497	9497	25 process. The procurement administrator shall design and
9498	9498	26 issue a request for proposals to supply electricity in
9499	9499
9500	9500
9501	9501
9502	9502
9503	9503
9504	9504	HB5514 - 263 - LRB103 39335 CES 69496 b
9505	9505
9506	9506
9507	9507	HB5514- 264 -LRB103 39335 CES 69496 b HB5514 - 264 - LRB103 39335 CES 69496 b
9508	9508	HB5514 - 264 - LRB103 39335 CES 69496 b
9509	9509	1 accordance with each utility's procurement plan, as
9510	9510	2 approved by the Commission. The request for proposals
9511	9511	3 shall set forth a procedure for sealed, binding commitment
9512	9512	4 bidding with pay-as-bid settlement, and provision for
9513	9513	5 selection of bids on the basis of price.
9514	9514	6 (5) A plan for implementing contingencies in the event
9515	9515	7 of supplier default or failure of the procurement process
9516	9516	8 to fully meet the expected load requirement due to
9517	9517	9 insufficient supplier participation, Commission rejection
9518	9518	10 of results, or any other cause.
9519	9519	11 (i) Event of supplier default: In the event of
9520	9520	12 supplier default, the utility shall review the
9521	9521	13 contract of the defaulting supplier to determine if
9522	9522	14 the amount of supply is 200 megawatts or greater, and
9523	9523	15 if there are more than 60 days remaining of the
9524	9524	16 contract term. If both of these conditions are met,
9525	9525	17 and the default results in termination of the
9526	9526	18 contract, the utility shall immediately notify the
9527	9527	19 Illinois Power Agency that a request for proposals
9528	9528	20 must be issued to procure replacement power, and the
9529	9529	21 procurement administrator shall run an additional
9530	9530	22 procurement event. If the contracted supply of the
9531	9531	23 defaulting supplier is less than 200 megawatts or
9532	9532	24 there are less than 60 days remaining of the contract
9533	9533	25 term, the utility shall procure power and energy from
9534	9534	26 the applicable regional transmission organization
9535	9535
9536	9536
9537	9537
9538	9538
9539	9539
9540	9540	HB5514 - 264 - LRB103 39335 CES 69496 b
9541	9541
9542	9542
9543	9543	HB5514- 265 -LRB103 39335 CES 69496 b HB5514 - 265 - LRB103 39335 CES 69496 b
9544	9544	HB5514 - 265 - LRB103 39335 CES 69496 b
9545	9545	1 market, including ancillary services, capacity, and
9546	9546	2 day-ahead or real time energy, or both, for the
9547	9547	3 duration of the contract term to replace the
9548	9548	4 contracted supply; provided, however, that if a needed
9549	9549	5 product is not available through the regional
9550	9550	6 transmission organization market it shall be purchased
9551	9551	7 from the wholesale market.
9552	9552	8 (ii) Failure of the procurement process to fully
9553	9553	9 meet the expected load requirement: If the procurement
9554	9554	10 process fails to fully meet the expected load
9555	9555	11 requirement due to insufficient supplier participation
9556	9556	12 or due to a Commission rejection of the procurement
9557	9557	13 results, the procurement administrator, the
9558	9558	14 procurement monitor, and the Commission staff shall
9559	9559	15 meet within 10 days to analyze potential causes of low
9560	9560	16 supplier interest or causes for the Commission
9561	9561	17 decision. If changes are identified that would likely
9562	9562	18 result in increased supplier participation, or that
9563	9563	19 would address concerns causing the Commission to
9564	9564	20 reject the results of the prior procurement event, the
9565	9565	21 procurement administrator may implement those changes
9566	9566	22 and rerun the request for proposals process according
9567	9567	23 to a schedule determined by those parties and
9568	9568	24 consistent with Section 1-75 of the Illinois Power
9569	9569	25 Agency Act and this subsection. In any event, a new
9570	9570	26 request for proposals process shall be implemented by
9571	9571
9572	9572
9573	9573
9574	9574
9575	9575
9576	9576	HB5514 - 265 - LRB103 39335 CES 69496 b
9577	9577
9578	9578
9579	9579	HB5514- 266 -LRB103 39335 CES 69496 b HB5514 - 266 - LRB103 39335 CES 69496 b
9580	9580	HB5514 - 266 - LRB103 39335 CES 69496 b
9581	9581	1 the procurement administrator within 90 days after the
9582	9582	2 determination that the procurement process has failed
9583	9583	3 to fully meet the expected load requirement.
9584	9584	4 (iii) In all cases where there is insufficient
9585	9585	5 supply provided under contracts awarded through the
9586	9586	6 procurement process to fully meet the electric
9587	9587	7 utility's load requirement, the utility shall meet the
9588	9588	8 load requirement by procuring power and energy from
9589	9589	9 the applicable regional transmission organization
9590	9590	10 market, including ancillary services, capacity, and
9591	9591	11 day-ahead or real time energy, or both; provided,
9592	9592	12 however, that if a needed product is not available
9593	9593	13 through the regional transmission organization market
9594	9594	14 it shall be purchased from the wholesale market.
9595	9595	15 (6) The procurement processes described in this
9596	9596	16 subsection and in subsection (c-5) and (c-7) of Section
9597	9597	17 1-75 of the Illinois Power Agency Act are exempt from the
9598	9598	18 requirements of the Illinois Procurement Code, pursuant to
9599	9599	19 Section 20-10 of that Code.
9600	9600	20 (f) Within 2 business days after opening the sealed bids,
9601	9601	21 the procurement administrator shall submit a confidential
9602	9602	22 report to the Commission. The report shall contain the results
9603	9603	23 of the bidding for each of the products along with the
9604	9604	24 procurement administrator's recommendation for the acceptance
9605	9605	25 and rejection of bids based on the price benchmark criteria
9606	9606	26 and other factors observed in the process. The procurement
9607	9607
9608	9608
9609	9609
9610	9610
9611	9611
9612	9612	HB5514 - 266 - LRB103 39335 CES 69496 b
9613	9613
9614	9614
9615	9615	HB5514- 267 -LRB103 39335 CES 69496 b HB5514 - 267 - LRB103 39335 CES 69496 b
9616	9616	HB5514 - 267 - LRB103 39335 CES 69496 b
9617	9617	1 monitor also shall submit a confidential report to the
9618	9618	2 Commission within 2 business days after opening the sealed
9619	9619	3 bids. The report shall contain the procurement monitor's
9620	9620	4 assessment of bidder behavior in the process as well as an
9621	9621	5 assessment of the procurement administrator's compliance with
9622	9622	6 the procurement process and rules. The Commission shall review
9623	9623	7 the confidential reports submitted by the procurement
9624	9624	8 administrator and procurement monitor, and shall accept or
9625	9625	9 reject the recommendations of the procurement administrator
9626	9626	10 within 2 business days after receipt of the reports.
9627	9627	11 (g) Within 3 business days after the Commission decision
9628	9628	12 approving the results of a procurement event, the utility
9629	9629	13 shall enter into binding contractual arrangements with the
9630	9630	14 winning suppliers using the standard form contracts; except
9631	9631	15 that the utility shall not be required either directly or
9632	9632	16 indirectly to execute the contracts if a tariff that is
9633	9633	17 consistent with subsection (l) of this Section has not been
9634	9634	18 approved and placed into effect for that utility.
9635	9635	19 (h) For the procurement of standard wholesale products,
9636	9636	20 the names of the successful bidders and the load weighted
9637	9637	21 average of the winning bid prices for each contract type and
9638	9638	22 for each contract term shall be made available to the public at
9639	9639	23 the time of Commission approval of a procurement event. For
9640	9640	24 procurements conducted to meet the requirements of subsection
9641	9641	25 (b) of Section 1-56 or subsection (c) of Section 1-75 of the
9642	9642	26 Illinois Power Agency Act governed by the provisions of this
9643	9643
9644	9644
9645	9645
9646	9646
9647	9647
9648	9648	HB5514 - 267 - LRB103 39335 CES 69496 b
9649	9649
9650	9650
9651	9651	HB5514- 268 -LRB103 39335 CES 69496 b HB5514 - 268 - LRB103 39335 CES 69496 b
9652	9652	HB5514 - 268 - LRB103 39335 CES 69496 b
9653	9653	1 Section, the address and nameplate capacity of the new
9654	9654	2 renewable energy generating facility proposed by a winning
9655	9655	3 bidder shall also be made available to the public at the time
9656	9656	4 of Commission approval of a procurement event, along with the
9657	9657	5 business address and contact information for any winning
9658	9658	6 bidder. An estimate or approximation of the nameplate capacity
9659	9659	7 of the new renewable energy generating facility may be
9660	9660	8 disclosed if necessary to protect the confidentiality of
9661	9661	9 individual bid prices.
9662	9662	10 The Commission, the procurement monitor, the procurement
9663	9663	11 administrator, the Illinois Power Agency, and all participants
9664	9664	12 in the procurement process shall maintain the confidentiality
9665	9665	13 of all other supplier and bidding information in a manner
9666	9666	14 consistent with all applicable laws, rules, regulations, and
9667	9667	15 tariffs. Confidential information, including the confidential
9668	9668	16 reports submitted by the procurement administrator and
9669	9669	17 procurement monitor pursuant to subsection (f) of this
9670	9670	18 Section, shall not be made publicly available and shall not be
9671	9671	19 discoverable by any party in any proceeding, absent a
9672	9672	20 compelling demonstration of need, nor shall those reports be
9673	9673	21 admissible in any proceeding other than one for law
9674	9674	22 enforcement purposes.
9675	9675	23 (i) Within 2 business days after a Commission decision
9676	9676	24 approving the results of a procurement event or such other
9677	9677	25 date as may be required by the Commission from time to time,
9678	9678	26 the utility shall file for informational purposes with the
9679	9679
9680	9680
9681	9681
9682	9682
9683	9683
9684	9684	HB5514 - 268 - LRB103 39335 CES 69496 b
9685	9685
9686	9686
9687	9687	HB5514- 269 -LRB103 39335 CES 69496 b HB5514 - 269 - LRB103 39335 CES 69496 b
9688	9688	HB5514 - 269 - LRB103 39335 CES 69496 b
9689	9689	1 Commission its actual or estimated retail supply charges, as
9690	9690	2 applicable, by customer supply group reflecting the costs
9691	9691	3 associated with the procurement and computed in accordance
9692	9692	4 with the tariffs filed pursuant to subsection (l) of this
9693	9693	5 Section and approved by the Commission.
9694	9694	6 (j) Within 60 days following August 28, 2007 (the
9695	9695	7 effective date of Public Act 95-481), each electric utility
9696	9696	8 that on December 31, 2005 provided electric service to at
9697	9697	9 least 100,000 customers in Illinois shall prepare and file
9698	9698	10 with the Commission an initial procurement plan, which shall
9699	9699	11 conform in all material respects to the requirements of the
9700	9700	12 procurement plan set forth in subsection (b); provided,
9701	9701	13 however, that the Illinois Power Agency Act shall not apply to
9702	9702	14 the initial procurement plan prepared pursuant to this
9703	9703	15 subsection. The initial procurement plan shall identify the
9704	9704	16 portfolio of power and energy products to be procured and
9705	9705	17 delivered for the period June 2008 through May 2009, and shall
9706	9706	18 identify the proposed procurement administrator, who shall
9707	9707	19 have the same experience and expertise as is required of a
9708	9708	20 procurement administrator hired pursuant to Section 1-75 of
9709	9709	21 the Illinois Power Agency Act. Copies of the procurement plan
9710	9710	22 shall be posted and made publicly available on the
9711	9711	23 Commission's website. The initial procurement plan may include
9712	9712	24 contracts for renewable resources that extend beyond May 2009.
9713	9713	25 (i) Within 14 days following filing of the initial
9714	9714	26 procurement plan, any person may file a detailed objection
9715	9715
9716	9716
9717	9717
9718	9718
9719	9719
9720	9720	HB5514 - 269 - LRB103 39335 CES 69496 b
9721	9721
9722	9722
9723	9723	HB5514- 270 -LRB103 39335 CES 69496 b HB5514 - 270 - LRB103 39335 CES 69496 b
9724	9724	HB5514 - 270 - LRB103 39335 CES 69496 b
9725	9725	1 with the Commission contesting the procurement plan
9726	9726	2 submitted by the electric utility. All objections to the
9727	9727	3 electric utility's plan shall be specific, supported by
9728	9728	4 data or other detailed analyses. The electric utility may
9729	9729	5 file a response to any objections to its procurement plan
9730	9730	6 within 7 days after the date objections are due to be
9731	9731	7 filed. Within 7 days after the date the utility's response
9732	9732	8 is due, the Commission shall determine whether a hearing
9733	9733	9 is necessary. If it determines that a hearing is
9734	9734	10 necessary, it shall require the hearing to be completed
9735	9735	11 and issue an order on the procurement plan within 60 days
9736	9736	12 after the filing of the procurement plan by the electric
9737	9737	13 utility.
9738	9738	14 (ii) The order shall approve or modify the procurement
9739	9739	15 plan, approve an independent procurement administrator,
9740	9740	16 and approve or modify the electric utility's tariffs that
9741	9741	17 are proposed with the initial procurement plan. The
9742	9742	18 Commission shall approve the procurement plan if the
9743	9743	19 Commission determines that it will ensure adequate,
9744	9744	20 reliable, affordable, efficient, and environmentally
9745	9745	21 sustainable electric service at the lowest total cost over
9746	9746	22 time, taking into account any benefits of price stability.
9747	9747	23 (k) (Blank).
9748	9748	24 (k-5) (Blank).
9749	9749	25 (l) An electric utility shall recover its costs incurred
9750	9750	26 under this Section and subsection (c-5) of Section 1-75 of the
9751	9751
9752	9752
9753	9753
9754	9754
9755	9755
9756	9756	HB5514 - 270 - LRB103 39335 CES 69496 b
9757	9757
9758	9758
9759	9759	HB5514- 271 -LRB103 39335 CES 69496 b HB5514 - 271 - LRB103 39335 CES 69496 b
9760	9760	HB5514 - 271 - LRB103 39335 CES 69496 b
9761	9761	1 Illinois Power Agency Act, including, but not limited to, the
9762	9762	2 costs of procuring power and energy demand-response resources
9763	9763	3 under this Section and its costs for purchasing renewable
9764	9764	4 energy credits pursuant to subsection (c-5) of Section 1-75 of
9765	9765	5 the Illinois Power Agency Act and (c-7). The utility shall
9766	9766	6 file with the initial procurement plan its proposed tariffs
9767	9767	7 through which its costs of procuring power that are incurred
9768	9768	8 pursuant to a Commission-approved procurement plan and those
9769	9769	9 other costs identified in this subsection (l), will be
9770	9770	10 recovered. The tariffs shall include a formula rate or charge
9771	9771	11 designed to pass through both the costs incurred by the
9772	9772	12 utility in procuring a supply of electric power and energy for
9773	9773	13 the applicable customer classes with no mark-up or return on
9774	9774	14 the price paid by the utility for that supply, plus any just
9775	9775	15 and reasonable costs that the utility incurs in arranging and
9776	9776	16 providing for the supply of electric power and energy. The
9777	9777	17 formula rate or charge shall also contain provisions that
9778	9778	18 ensure that its application does not result in over or under
9779	9779	19 recovery due to changes in customer usage and demand patterns,
9780	9780	20 and that provide for the correction, on at least an annual
9781	9781	21 basis, of any accounting errors that may occur. A utility
9782	9782	22 shall recover through the tariff all reasonable costs incurred
9783	9783	23 to implement or comply with any procurement plan that is
9784	9784	24 developed and put into effect pursuant to Section 1-75 of the
9785	9785	25 Illinois Power Agency Act and this Section, and for the
9786	9786	26 procurement of renewable energy credits pursuant to subsection
9787	9787
9788	9788
9789	9789
9790	9790
9791	9791
9792	9792	HB5514 - 271 - LRB103 39335 CES 69496 b
9793	9793
9794	9794
9795	9795	HB5514- 272 -LRB103 39335 CES 69496 b HB5514 - 272 - LRB103 39335 CES 69496 b
9796	9796	HB5514 - 272 - LRB103 39335 CES 69496 b
9797	9797	1 (c-5) or (c-7) of Section 1-75 of the Illinois Power Agency
9798	9798	2 Act, including any fees assessed by the Illinois Power Agency,
9799	9799	3 costs associated with load balancing, and contingency plan
9800	9800	4 costs. The electric utility shall also recover its full costs
9801	9801	5 of procuring electric supply for which it contracted before
9802	9802	6 the effective date of this Section in conjunction with the
9803	9803	7 provision of full requirements service under fixed-price
9804	9804	8 bundled service tariffs subsequent to December 31, 2006. All
9805	9805	9 such costs shall be deemed to have been prudently incurred.
9806	9806	10 The pass-through tariffs that are filed and approved pursuant
9807	9807	11 to this Section shall not be subject to review under, or in any
9808	9808	12 way limited by, Section 16-111(i) of this Act. All of the costs
9809	9809	13 incurred by the electric utility associated with the purchase
9810	9810	14 of zero emission credits in accordance with subsection (d-5)
9811	9811	15 of Section 1-75 of the Illinois Power Agency Act, all costs
9812	9812	16 incurred by the electric utility associated with the purchase
9813	9813	17 of carbon mitigation credits in accordance with subsection
9814	9814	18 (d-10) of Section 1-75 of the Illinois Power Agency Act, and,
9815	9815	19 beginning June 1, 2017, all of the costs incurred by the
9816	9816	20 electric utility associated with the purchase of renewable
9817	9817	21 energy resources in accordance with Sections 1-56 and 1-75 of
9818	9818	22 the Illinois Power Agency Act, and all of the costs incurred by
9819	9819	23 the electric utility in purchasing renewable energy credits in
9820	9820	24 accordance with subsection (c-5) of Section 1-75 of the
9821	9821	25 Illinois Power Agency Act, shall be recovered through the
9822	9822	26 electric utility's tariffed charges applicable to all of its
9823	9823
9824	9824
9825	9825
9826	9826
9827	9827
9828	9828	HB5514 - 272 - LRB103 39335 CES 69496 b
9829	9829
9830	9830
9831	9831	HB5514- 273 -LRB103 39335 CES 69496 b HB5514 - 273 - LRB103 39335 CES 69496 b
9832	9832	HB5514 - 273 - LRB103 39335 CES 69496 b
9833	9833	1 retail customers, as specified in subsection (k), or
9834	9834	2 subsection (i-5), or (i-7) as applicable, of Section 16-108 of
9835	9835	3 this Act, and shall not be recovered through the electric
9836	9836	4 utility's tariffed charges for electric power and energy
9837	9837	5 supply to its eligible retail customers.
9838	9838	6 (m) The Commission has the authority to adopt rules to
9839	9839	7 carry out the provisions of this Section. For the public
9840	9840	8 interest, safety, and welfare, the Commission also has
9841	9841	9 authority to adopt rules to carry out the provisions of this
9842	9842	10 Section on an emergency basis immediately following August 28,
9843	9843	11 2007 (the effective date of Public Act 95-481).
9844	9844	12 (n) Notwithstanding any other provision of this Act, any
9845	9845	13 affiliated electric utilities that submit a single procurement
9846	9846	14 plan covering their combined needs may procure for those
9847	9847	15 combined needs in conjunction with that plan, and may enter
9848	9848	16 jointly into power supply contracts, purchases, and other
9849	9849	17 procurement arrangements, and allocate capacity and energy and
9850	9850	18 cost responsibility therefor among themselves in proportion to
9851	9851	19 their requirements.
9852	9852	20 (o) On or before June 1 of each year, the Commission shall
9853	9853	21 hold an informal hearing for the purpose of receiving comments
9854	9854	22 on the prior year's procurement process and any
9855	9855	23 recommendations for change.
9856	9856	24 (p) An electric utility subject to this Section may
9857	9857	25 propose to invest, lease, own, or operate an electric
9858	9858	26 generation facility or high voltage direct current
9859	9859
9860	9860
9861	9861
9862	9862
9863	9863
9864	9864	HB5514 - 273 - LRB103 39335 CES 69496 b
9865	9865
9866	9866
9867	9867	HB5514- 274 -LRB103 39335 CES 69496 b HB5514 - 274 - LRB103 39335 CES 69496 b
9868	9868	HB5514 - 274 - LRB103 39335 CES 69496 b
9869	9869	1 transmission line as part of its procurement plan, provided
9870	9870	2 the utility demonstrates that such facility is the least-cost
9871	9871	3 option to provide electric service to those retail customers
9872	9872	4 included in the plan's electric supply service requirements.
9873	9873	5 If the facility is shown to be the least-cost option and is
9874	9874	6 included in a procurement plan prepared in accordance with
9875	9875	7 Section 1-75 of the Illinois Power Agency Act and this
9876	9876	8 Section, then the electric utility shall make a filing
9877	9877	9 pursuant to Section 8-406 of this Act, and may request of the
9878	9878	10 Commission any statutory relief required thereunder. If the
9879	9879	11 Commission grants all of the necessary approvals for the
9880	9880	12 proposed facility, such supply shall thereafter be considered
9881	9881	13 as a pre-existing contract under subsection (b) of this
9882	9882	14 Section. The Commission shall in any order approving a
9883	9883	15 proposal under this subsection specify how the utility will
9884	9884	16 recover the prudently incurred costs of investing in, leasing,
9885	9885	17 owning, or operating such generation facility through just and
9886	9886	18 reasonable rates charged to those retail customers included in
9887	9887	19 the plan's electric supply service requirements. Cost recovery
9888	9888	20 for facilities included in the utility's procurement plan
9889	9889	21 pursuant to this subsection shall not be subject to review
9890	9890	22 under or in any way limited by the provisions of Section
9891	9891	23 16-111(i) of this Act. Nothing in this Section is intended to
9892	9892	24 prohibit a utility from filing for a fuel adjustment clause as
9893	9893	25 is otherwise permitted under Section 9-220 of this Act.
9894	9894	26 (q) If the Illinois Power Agency filed with the
9895	9895
9896	9896
9897	9897
9898	9898
9899	9899
9900	9900	HB5514 - 274 - LRB103 39335 CES 69496 b
9901	9901
9902	9902
9903	9903	HB5514- 275 -LRB103 39335 CES 69496 b HB5514 - 275 - LRB103 39335 CES 69496 b
9904	9904	HB5514 - 275 - LRB103 39335 CES 69496 b
9905	9905	1 Commission, under Section 16-111.5 of this Act, its proposed
9906	9906	2 procurement plan for the period commencing June 1, 2017, and
9907	9907	3 the Commission has not yet entered its final order approving
9908	9908	4 the plan on or before the effective date of this amendatory Act
9909	9909	5 of the 99th General Assembly, then the Illinois Power Agency
9910	9910	6 shall file a notice of withdrawal with the Commission, after
9911	9911	7 the effective date of this amendatory Act of the 99th General
9912	9912	8 Assembly, to withdraw the proposed procurement of renewable
9913	9913	9 energy resources to be approved under the plan, other than the
9914	9914	10 procurement of renewable energy credits from distributed
9915	9915	11 renewable energy generation devices using funds previously
9916	9916	12 collected from electric utilities' retail customers that take
9917	9917	13 service pursuant to electric utilities' hourly pricing tariff
9918	9918	14 or tariffs and, for an electric utility that serves less than
9919	9919	15 100,000 retail customers in the State, other than the
9920	9920	16 procurement of renewable energy credits from distributed
9921	9921	17 renewable energy generation devices. Upon receipt of the
9922	9922	18 notice, the Commission shall enter an order that approves the
9923	9923	19 withdrawal of the proposed procurement of renewable energy
9924	9924	20 resources from the plan. The initially proposed procurement of
9925	9925	21 renewable energy resources shall not be approved or be the
9926	9926	22 subject of any further hearing, investigation, proceeding, or
9927	9927	23 order of any kind.
9928	9928	24 This amendatory Act of the 99th General Assembly preempts
9929	9929	25 and supersedes any order entered by the Commission that
9930	9930	26 approved the Illinois Power Agency's procurement plan for the
9931	9931
9932	9932
9933	9933
9934	9934
9935	9935
9936	9936	HB5514 - 275 - LRB103 39335 CES 69496 b
9937	9937
9938	9938
9939	9939	HB5514- 276 -LRB103 39335 CES 69496 b HB5514 - 276 - LRB103 39335 CES 69496 b
9940	9940	HB5514 - 276 - LRB103 39335 CES 69496 b
9941	9941
9942	9942
9943	9943
9944	9944
9945	9945
9946	9946	HB5514 - 276 - LRB103 39335 CES 69496 b