Illinois 2025-2026 Regular Session

Illinois Senate Bill SB1442 Compare Versions

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

Old	New	Differences
1	1	104TH GENERAL ASSEMBLY State of Illinois 2025 and 2026 SB1442 Introduced 1/31/2025, by Sen. Robert Peters SYNOPSIS AS INTRODUCED: New Act20 ILCS 3855/1-7530 ILCS 105/5.1030 new Creates the Illinois Rust Belt to Green Belt Pilot Program Act. Creates the Illinois Rust Belt to Green Belt Fund as a special fund in the State treasury and makes a conforming change in the State Finance Act. Provides that the Fund shall be used by the Department of Commerce and Economic Opportunity to encourage and facilitate the employment of construction workforces located in underrepresented populations. Provides that applicants that are applying for a new utility-scale offshore wind project with the Illinois Power Agency shall file with the Department, as part of the applicant's application, an equity and inclusion plan. Amends the Illinois Power Agency Act. In provisions concerning the procurement of renewable energy credits, provides that in addition to the amount of renewable energy credits to be procured from wind projects, the Illinois Power Agency shall procure at least 700,000 renewable energy credits, delivered annually for at least 20 years, from one new utility-scale offshore wind project. In provisions concerning the development of a long-term renewable resources procurement plan, provides that the total of renewable energy resources procured under the procurement plan shall be reduced for all retail customers based on the amount necessary to limit the annual estimated average net increase due to the costs of these resources included in the amounts paid by eligible retail customers in connection with electric service to no more than 4.25% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009, and to no more than 4.5% of that amount as of the billing month following the expected date that a new utility-scale offshore wind project commences commercial operations and is expected to begin delivering power to the PJM Interconnection, LLC transmission grid. Provides that the Agency shall conduct at least one new utility-scale offshore wind procurement within 360 days after the effective date of the amendatory Act. Defines terms. Makes other changes. Effective immediately. LRB104 11424 BDA 21512 b A BILL FOR 104TH GENERAL ASSEMBLY State of Illinois 2025 and 2026 SB1442 Introduced 1/31/2025, by Sen. Robert Peters SYNOPSIS AS INTRODUCED: New Act20 ILCS 3855/1-7530 ILCS 105/5.1030 new New Act 20 ILCS 3855/1-75 30 ILCS 105/5.1030 new Creates the Illinois Rust Belt to Green Belt Pilot Program Act. Creates the Illinois Rust Belt to Green Belt Fund as a special fund in the State treasury and makes a conforming change in the State Finance Act. Provides that the Fund shall be used by the Department of Commerce and Economic Opportunity to encourage and facilitate the employment of construction workforces located in underrepresented populations. Provides that applicants that are applying for a new utility-scale offshore wind project with the Illinois Power Agency shall file with the Department, as part of the applicant's application, an equity and inclusion plan. Amends the Illinois Power Agency Act. In provisions concerning the procurement of renewable energy credits, provides that in addition to the amount of renewable energy credits to be procured from wind projects, the Illinois Power Agency shall procure at least 700,000 renewable energy credits, delivered annually for at least 20 years, from one new utility-scale offshore wind project. In provisions concerning the development of a long-term renewable resources procurement plan, provides that the total of renewable energy resources procured under the procurement plan shall be reduced for all retail customers based on the amount necessary to limit the annual estimated average net increase due to the costs of these resources included in the amounts paid by eligible retail customers in connection with electric service to no more than 4.25% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009, and to no more than 4.5% of that amount as of the billing month following the expected date that a new utility-scale offshore wind project commences commercial operations and is expected to begin delivering power to the PJM Interconnection, LLC transmission grid. Provides that the Agency shall conduct at least one new utility-scale offshore wind procurement within 360 days after the effective date of the amendatory Act. Defines terms. Makes other changes. Effective immediately. LRB104 11424 BDA 21512 b LRB104 11424 BDA 21512 b A BILL FOR
2	2	104TH GENERAL ASSEMBLY State of Illinois 2025 and 2026 SB1442 Introduced 1/31/2025, by Sen. Robert Peters SYNOPSIS AS INTRODUCED:
3	3	New Act20 ILCS 3855/1-7530 ILCS 105/5.1030 new New Act 20 ILCS 3855/1-75 30 ILCS 105/5.1030 new
4	4	New Act
5	5	20 ILCS 3855/1-75
6	6	30 ILCS 105/5.1030 new
7	7	Creates the Illinois Rust Belt to Green Belt Pilot Program Act. Creates the Illinois Rust Belt to Green Belt Fund as a special fund in the State treasury and makes a conforming change in the State Finance Act. Provides that the Fund shall be used by the Department of Commerce and Economic Opportunity to encourage and facilitate the employment of construction workforces located in underrepresented populations. Provides that applicants that are applying for a new utility-scale offshore wind project with the Illinois Power Agency shall file with the Department, as part of the applicant's application, an equity and inclusion plan. Amends the Illinois Power Agency Act. In provisions concerning the procurement of renewable energy credits, provides that in addition to the amount of renewable energy credits to be procured from wind projects, the Illinois Power Agency shall procure at least 700,000 renewable energy credits, delivered annually for at least 20 years, from one new utility-scale offshore wind project. In provisions concerning the development of a long-term renewable resources procurement plan, provides that the total of renewable energy resources procured under the procurement plan shall be reduced for all retail customers based on the amount necessary to limit the annual estimated average net increase due to the costs of these resources included in the amounts paid by eligible retail customers in connection with electric service to no more than 4.25% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009, and to no more than 4.5% of that amount as of the billing month following the expected date that a new utility-scale offshore wind project commences commercial operations and is expected to begin delivering power to the PJM Interconnection, LLC transmission grid. Provides that the Agency shall conduct at least one new utility-scale offshore wind procurement within 360 days after the effective date of the amendatory Act. Defines terms. Makes other changes. Effective immediately.
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13	13	1 AN ACT concerning regulation.
14	14	2 Be it enacted by the People of the State of Illinois,
15	15	3 represented in the General Assembly:
16	16	4 Section 1. Short title. This Act may be cited as the
17	17	5 Illinois Rust Belt to Green Belt Pilot Program Act.
18	18	6 Section 5. Legislative findings. The General Assembly
19	19	7 finds and determines that:
20	20	8 (1) Human-induced greenhouse gas emissions have been
21	21	9 identified as contributing to global warming, the effects
22	22	10 of which pose a threat to the public health, safety,
23	23	11 welfare, and economy of the State.
24	24	12 (2) The White House released a statement claiming
25	25	13 that, in 2020, the United States endured 22 separate
26	26	14 billion-dollar weather and climate disasters, costing
27	27	15 $95,000,000,000 in damages to homes, businesses, and
28	28	16 public infrastructure.
29	29	17 (3) In order to meet the energy needs of the State,
30	30	18 keep its economy strong, and protect the environment while
31	31	19 reducing its contribution to human-induced greenhouse gas
32	32	20 emissions, the State must be a leader in developing new
33	33	21 low-carbon technologies.
34	34	22 (4) Offshore wind is an emerging source of large-scale
35	35	23 renewable energy that is proximate to Illinois' major
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39	39	104TH GENERAL ASSEMBLY State of Illinois 2025 and 2026 SB1442 Introduced 1/31/2025, by Sen. Robert Peters SYNOPSIS AS INTRODUCED:
40	40	New Act20 ILCS 3855/1-7530 ILCS 105/5.1030 new New Act 20 ILCS 3855/1-75 30 ILCS 105/5.1030 new
41	41	New Act
42	42	20 ILCS 3855/1-75
43	43	30 ILCS 105/5.1030 new
44	44	Creates the Illinois Rust Belt to Green Belt Pilot Program Act. Creates the Illinois Rust Belt to Green Belt Fund as a special fund in the State treasury and makes a conforming change in the State Finance Act. Provides that the Fund shall be used by the Department of Commerce and Economic Opportunity to encourage and facilitate the employment of construction workforces located in underrepresented populations. Provides that applicants that are applying for a new utility-scale offshore wind project with the Illinois Power Agency shall file with the Department, as part of the applicant's application, an equity and inclusion plan. Amends the Illinois Power Agency Act. In provisions concerning the procurement of renewable energy credits, provides that in addition to the amount of renewable energy credits to be procured from wind projects, the Illinois Power Agency shall procure at least 700,000 renewable energy credits, delivered annually for at least 20 years, from one new utility-scale offshore wind project. In provisions concerning the development of a long-term renewable resources procurement plan, provides that the total of renewable energy resources procured under the procurement plan shall be reduced for all retail customers based on the amount necessary to limit the annual estimated average net increase due to the costs of these resources included in the amounts paid by eligible retail customers in connection with electric service to no more than 4.25% of the amount paid per kilowatthour by those customers during the year ending May 31, 2009, and to no more than 4.5% of that amount as of the billing month following the expected date that a new utility-scale offshore wind project commences commercial operations and is expected to begin delivering power to the PJM Interconnection, LLC transmission grid. Provides that the Agency shall conduct at least one new utility-scale offshore wind procurement within 360 days after the effective date of the amendatory Act. Defines terms. Makes other changes. Effective immediately.
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47	47	A BILL FOR
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53	53	New Act
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55	55	30 ILCS 105/5.1030 new
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74	74	1 electric loads and labor intensive.
75	75	2 (5) Offshore wind produces high capacity factor
76	76	3 renewable power, making it a valuable resource
77	77	4 complementary to land-based wind and solar.
78	78	5 (6) In his first week in office, President Joseph R.
79	79	6 Biden, Jr., issued Executive Order (14008) on Tackling the
80	80	7 Climate Crisis at Home and Abroad, which directs the
81	81	8 Secretary of the Interior to identify steps that can be
82	82	9 taken to double offshore wind by 2030 while "ensuring
83	83	10 robust protection for our lands, waters, and biodiversity
84	84	11 and creating good jobs".
85	85	12 (7) The United States Departments of Interior, Energy,
86	86	13 and Commerce announced a shared goal to deploy 30
87	87	14 gigawatts of offshore wind in the United States by 2030,
88	88	15 while protecting biodiversity and promoting ocean co-use,
89	89	16 which trigger more than $12,000,000,000 per year in
90	90	17 capital investment; create tens of thousands of
91	91	18 good-paying, union jobs, with more than 44,000 workers
92	92	19 employed in offshore wind by 2030 and nearly 33,000
93	93	20 additional jobs in communities supported by offshore wind
94	94	21 activity; generate enough power to meet the demand of more
95	95	22 than 10,000,000 American homes for a year; and avoid
96	96	23 78,000,000 metric tons of carbon dioxide emissions.
97	97	24 (8) The federal government is expanding infrastructure
98	98	25 funding for port rehabilitation and construction,
99	99	26 including the United States Department of Transportation's
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110	110	1 Maritime Administration's Notice of Funding Opportunity
111	111	2 for port authorities and other applicants to apply for
112	112	3 $230,000,000 for port and intermodal
113	113	4 infrastructure-related projects through the Port
114	114	5 Infrastructure Development Program to support projects
115	115	6 that strengthen and modernize port infrastructure, and can
116	116	7 support shore-side wind energy projects, such as storage
117	117	8 areas, laydown areas, and docking of wind energy vessels
118	118	9 to load and move items to offshore wind farms.
119	119	10 (9) Extensive development of offshore wind on the East
120	120	11 Coast is making offshore wind costs more competitive.
121	121	12 (10) Lake Michigan is the fifth largest lake in the
122	122	13 world, with a total surface area of 22,404 square miles
123	123	14 across 4 states, with 1,576 square miles of surface area
124	124	15 in Illinois.
125	125	16 (11) The 1,576 square miles of Lake Michigan within
126	126	17 the boundaries of the State have a potential capacity of
127	127	18 4,528 megawatts of offshore wind.
128	128	19 (12) The State has excellent and available port
129	129	20 infrastructure on the South Side of Chicago that can be
130	130	21 used as a base for construction, operations, and
131	131	22 maintenance.
132	132	23 (13) The State seeks a leadership position in the
133	133	24 offshore wind industry as it emerges in the Great Lakes.
134	134	25 (14) Fostering development of a new industry on the
135	135	26 South Side of Chicago will help create jobs for the most
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146	146	1 underserved and underrepresented segment of Illinois'
147	147	2 population.
148	148	3 (15) Offshore wind developments will attract
149	149	4 investment capital and will enable the development and
150	150	5 preservation of a skilled and trained construction
151	151	6 workforce to carry out projects, long-term job creation,
152	152	7 and development of an offshore wind energy supply chain.
153	153	8 Rates will not be impacted until after the offshore wind
154	154	9 development is energized and starts delivering power.
155	155	10 (16) The bed of Lake Michigan is held by the State in
156	156	11 public trust on behalf of the citizens of the State, and,
157	157	12 therefore, all offshore wind developments in Lake Michigan
158	158	13 are subject to obtaining permits from the Department of
159	159	14 Natural Resources pursuant to the Rivers, Lakes, and
160	160	15 Streams Act.
161	161	16 Therefore, the General Assembly finds that it is necessary
162	162	17 to enact this Act to enable the responsible creation of an
163	163	18 offshore wind industry in the State with the creation of a
164	164	19 pilot project of at least 150 megawatts to provide economic
165	165	20 and environmental benefits to the State.
166	166	21 Section 10. Definitions. As used in this Act:
167	167	22 "Department" means the Department of Commerce and Economic
168	168	23 Opportunity.
169	169	24 "Disproportionately impacted area" means a census tract or
170	170	25 comparable geographic area that satisfies criteria as
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181	181	1 determined by the Department.
182	182	2 "Equity and inclusion plan" means a plan that is filed
183	183	3 with the Department by an applicant for a new utility-scale
184	184	4 offshore wind project pursuant to item (iii-5) of subparagraph
185	185	5 (G) of paragraph (1) of subsection (c) of Section 1-75 of the
186	186	6 Illinois Power Agency Act.
187	187	7 "Equity and inclusion plan scoring" means a score of up to
188	188	8 34 points, determined by the Department's review of an
189	189	9 applicant's ability to demonstrate that it has a comprehensive
190	190	10 and detailed equity and inclusion plan crafted to create
191	191	11 opportunities for underrepresented populations and equity
192	192	12 investment eligible communities.
193	193	13 "Equity investment eligible communities" means "equity
194	194	14 investment eligible community" as defined in Section 5-5 of
195	195	15 the Energy Transition Act.
196	196	16 "Minorities" means "minority person" as defined in the
197	197	17 Business Enterprise for Minorities, Women, and Persons with
198	198	18 Disabilities Act.
199	199	19 "New utility-scale offshore wind project" means an
200	200	20 electric generating facility that:
201	201	21 (1) generates electricity using wind;
202	202	22 (2) has a nameplate capacity that is greater than 150
203	203	23 megawatts;
204	204	24 (3) is sited in the waters of Lake Michigan;
205	205	25 (4) is interconnected to the PJM Interconnection's
206	206	26 regional transmission system;
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217	217	1 (5) has a fully executed project labor agreement with
218	218	2 the applicable local building and construction trades
219	219	3 council for the length of the renewable energy credit
220	220	4 contract;
221	221	5 (6) has a comprehensive and detailed equity and
222	222	6 inclusion plan crafted to create opportunities for
223	223	7 underrepresented local populations in addition to equity
224	224	8 investment eligible communities; and
225	225	9 (7) has a permit pursuant to the Rivers, Lakes, and
226	226	10 Streams Act from the Department of Natural Resources.
227	227	11 "Underrepresented populations" means populations
228	228	12 identified by the Department that historically have had
229	229	13 barriers to entry or advancement in the workforce and reside
230	230	14 within a disproportionately impacted area that is within 3
231	231	15 miles of the primary staging location of a new utility-scale
232	232	16 offshore wind project. "Underrepresented populations"
233	233	17 includes, but is not limited to, minorities, women, and
234	234	18 veterans.
235	235	19 Section 15. Illinois Rust Belt to Green Belt Fund;
236	236	20 creation; distribution of proceeds.
237	237	21 (a) The Illinois Rust Belt to Green Belt Fund is created as
238	238	22 a special fund in the State treasury. The fund may receive
239	239	23 federal financial assistance, either directly from the federal
240	240	24 government or indirectly through another source, public or
241	241	25 private. The fund may also receive transfers, gifts, grants,
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252	252	1 or donations from any source, public or private. Subject to
253	253	2 appropriation, funds may be spent for purposes including, but
254	254	3 not limited to, administrative expenses of the Department,
255	255	4 grants and other financial assistance related to construction
256	256	5 of ports and infrastructure, and workforce development related
257	257	6 to offshore wind.
258	258	7 (b) The Illinois Rust Belt to Green Belt Fund shall be used
259	259	8 by the Department to encourage and facilitate the employment
260	260	9 of construction workforces located in underrepresented
261	261	10 populations, in addition to equity investment eligible
262	262	11 communities for work on a new utility-scale offshore wind
263	263	12 project or related port, and compliance with all rules and
264	264	13 regulations of the Environmental Protection Agency. Recipients
265	265	14 of grants or awards from the Illinois Rust Belt to Green Belt
266	266	15 Fund may utilize the Illinois Climate Works Preapprenticeship
267	267	16 Program, Clean Jobs Workforce Network Program, Clean Energy
268	268	17 Contractor Incubator Program, Returning Residents Clean Jobs
269	269	18 Training Program, and Clean Energy Primes Contractor
270	270	19 Accelerator Program as described in the Energy Transition Act
271	271	20 to recruit, prescreen, and provide pre-apprenticeship skills
272	272	21 training for work on a new utility-scale offshore wind project
273	273	22 or related port.
274	274	23 Section 20. Equity and inclusion plan; filing; scoring.
275	275	24 Applicants that are applying for a new utility-scale offshore
276	276	25 wind project with the Illinois Power Agency shall file with
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287	287	1 the Department, as part of the applicant's application, an
288	288	2 equity and inclusion plan. This equity and inclusion plan
289	289	3 shall include one or more community benefits agreements with
290	290	4 community-based organizations. For purposes of this Section,
291	291	5 "community-based organizations" means organizations that: (i)
292	292	6 provide employment training, readiness, or skill development
293	293	7 and facilitate economic development or related services to
294	294	8 members of the community; (ii) have at least one main
295	295	9 operating office in the community or region it services; and
296	296	10 (iii) are resident driven, where decisions are made by people
297	297	11 of the community. The Department shall accept all equity and
298	298	12 inclusion plans and shall issue equity and inclusion plan
299	299	13 scoring for each plan based upon the plan's ability to create
300	300	14 opportunities for (i) underrepresented populations and (ii)
301	301	15 equity investment eligible communities. The maximum number of
302	302	16 points that the Department can award for each plan is 34
303	303	17 points.
304	304	18 Section 100. The Illinois Power Agency Act is amended by
305	305	19 changing Section 1-75 as follows:
306	306	20 (20 ILCS 3855/1-75)
307	307	21 Sec. 1-75. Planning and Procurement Bureau. The Planning
308	308	22 and Procurement Bureau has the following duties and
309	309	23 responsibilities:
310	310	24 (a) The Planning and Procurement Bureau shall each year,
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321	321	1 beginning in 2008, develop procurement plans and conduct
322	322	2 competitive procurement processes in accordance with the
323	323	3 requirements of Section 16-111.5 of the Public Utilities Act
324	324	4 for the eligible retail customers of electric utilities that
325	325	5 on December 31, 2005 provided electric service to at least
326	326	6 100,000 customers in Illinois. Beginning with the delivery
327	327	7 year commencing on June 1, 2017, the Planning and Procurement
328	328	8 Bureau shall develop plans and processes for the procurement
329	329	9 of zero emission credits from zero emission facilities in
330	330	10 accordance with the requirements of subsection (d-5) of this
331	331	11 Section. Beginning on the effective date of this amendatory
332	332	12 Act of the 102nd General Assembly, the Planning and
333	333	13 Procurement Bureau shall develop plans and processes for the
334	334	14 procurement of carbon mitigation credits from carbon-free
335	335	15 energy resources in accordance with the requirements of
336	336	16 subsection (d-10) of this Section. The Planning and
337	337	17 Procurement Bureau shall also develop procurement plans and
338	338	18 conduct competitive procurement processes in accordance with
339	339	19 the requirements of Section 16-111.5 of the Public Utilities
340	340	20 Act for the eligible retail customers of small
341	341	21 multi-jurisdictional electric utilities that (i) on December
342	342	22 31, 2005 served less than 100,000 customers in Illinois and
343	343	23 (ii) request a procurement plan for their Illinois
344	344	24 jurisdictional load. This Section shall not apply to a small
345	345	25 multi-jurisdictional utility until such time as a small
346	346	26 multi-jurisdictional utility requests the Agency to prepare a
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357	357	1 procurement plan for their Illinois jurisdictional load. For
358	358	2 the purposes of this Section, the term "eligible retail
359	359	3 customers" has the same definition as found in Section
360	360	4 16-111.5(a) of the Public Utilities Act.
361	361	5 Beginning with the plan or plans to be implemented in the
362	362	6 2017 delivery year, the Agency shall no longer include the
363	363	7 procurement of renewable energy resources in the annual
364	364	8 procurement plans required by this subsection (a), except as
365	365	9 provided in subsection (q) of Section 16-111.5 of the Public
366	366	10 Utilities Act, and shall instead develop a long-term renewable
367	367	11 resources procurement plan in accordance with subsection (c)
368	368	12 of this Section and Section 16-111.5 of the Public Utilities
369	369	13 Act.
370	370	14 In accordance with subsection (c-5) of this Section, the
371	371	15 Planning and Procurement Bureau shall oversee the procurement
372	372	16 by electric utilities that served more than 300,000 retail
373	373	17 customers in this State as of January 1, 2019 of renewable
374	374	18 energy credits from new utility-scale solar projects to be
375	375	19 installed, along with energy storage facilities, at or
376	376	20 adjacent to the sites of electric generating facilities that,
377	377	21 as of January 1, 2016, burned coal as their primary fuel
378	378	22 source.
379	379	23 (1) The Agency shall each year, beginning in 2008, as
380	380	24 needed, issue a request for qualifications for experts or
381	381	25 expert consulting firms to develop the procurement plans
382	382	26 in accordance with Section 16-111.5 of the Public
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393	393	1 Utilities Act. In order to qualify an expert or expert
394	394	2 consulting firm must have:
395	395	3 (A) direct previous experience assembling
396	396	4 large-scale power supply plans or portfolios for
397	397	5 end-use customers;
398	398	6 (B) an advanced degree in economics, mathematics,
399	399	7 engineering, risk management, or a related area of
400	400	8 study;
401	401	9 (C) 10 years of experience in the electricity
402	402	10 sector, including managing supply risk;
403	403	11 (D) expertise in wholesale electricity market
404	404	12 rules, including those established by the Federal
405	405	13 Energy Regulatory Commission and regional transmission
406	406	14 organizations;
407	407	15 (E) expertise in credit protocols and familiarity
408	408	16 with contract protocols;
409	409	17 (F) adequate resources to perform and fulfill the
410	410	18 required functions and responsibilities; and
411	411	19 (G) the absence of a conflict of interest and
412	412	20 inappropriate bias for or against potential bidders or
413	413	21 the affected electric utilities.
414	414	22 (2) The Agency shall each year, as needed, issue a
415	415	23 request for qualifications for a procurement administrator
416	416	24 to conduct the competitive procurement processes in
417	417	25 accordance with Section 16-111.5 of the Public Utilities
418	418	26 Act. In order to qualify an expert or expert consulting
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429	429	1 firm must have:
430	430	2 (A) direct previous experience administering a
431	431	3 large-scale competitive procurement process;
432	432	4 (B) an advanced degree in economics, mathematics,
433	433	5 engineering, or a related area of study;
434	434	6 (C) 10 years of experience in the electricity
435	435	7 sector, including risk management experience;
436	436	8 (D) expertise in wholesale electricity market
437	437	9 rules, including those established by the Federal
438	438	10 Energy Regulatory Commission and regional transmission
439	439	11 organizations;
440	440	12 (E) expertise in credit and contract protocols;
441	441	13 (F) adequate resources to perform and fulfill the
442	442	14 required functions and responsibilities; and
443	443	15 (G) the absence of a conflict of interest and
444	444	16 inappropriate bias for or against potential bidders or
445	445	17 the affected electric utilities.
446	446	18 (3) The Agency shall provide affected utilities and
447	447	19 other interested parties with the lists of qualified
448	448	20 experts or expert consulting firms identified through the
449	449	21 request for qualifications processes that are under
450	450	22 consideration to develop the procurement plans and to
451	451	23 serve as the procurement administrator. The Agency shall
452	452	24 also provide each qualified expert's or expert consulting
453	453	25 firm's response to the request for qualifications. All
454	454	26 information provided under this subparagraph shall also be
455	455
456	456
457	457
458	458
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461	461
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465	465	1 provided to the Commission. The Agency may provide by rule
466	466	2 for fees associated with supplying the information to
467	467	3 utilities and other interested parties. These parties
468	468	4 shall, within 5 business days, notify the Agency in
469	469	5 writing if they object to any experts or expert consulting
470	470	6 firms on the lists. Objections shall be based on:
471	471	7 (A) failure to satisfy qualification criteria;
472	472	8 (B) identification of a conflict of interest; or
473	473	9 (C) evidence of inappropriate bias for or against
474	474	10 potential bidders or the affected utilities.
475	475	11 The Agency shall remove experts or expert consulting
476	476	12 firms from the lists within 10 days if there is a
477	477	13 reasonable basis for an objection and provide the updated
478	478	14 lists to the affected utilities and other interested
479	479	15 parties. If the Agency fails to remove an expert or expert
480	480	16 consulting firm from a list, an objecting party may seek
481	481	17 review by the Commission within 5 days thereafter by
482	482	18 filing a petition, and the Commission shall render a
483	483	19 ruling on the petition within 10 days. There is no right of
484	484	20 appeal of the Commission's ruling.
485	485	21 (4) The Agency shall issue requests for proposals to
486	486	22 the qualified experts or expert consulting firms to
487	487	23 develop a procurement plan for the affected utilities and
488	488	24 to serve as procurement administrator.
489	489	25 (5) The Agency shall select an expert or expert
490	490	26 consulting firm to develop procurement plans based on the
491	491
492	492
493	493
494	494
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501	501	1 proposals submitted and shall award contracts of up to 5
502	502	2 years to those selected.
503	503	3 (6) The Agency shall select an expert or expert
504	504	4 consulting firm, with approval of the Commission, to serve
505	505	5 as procurement administrator based on the proposals
506	506	6 submitted. If the Commission rejects, within 5 days, the
507	507	7 Agency's selection, the Agency shall submit another
508	508	8 recommendation within 3 days based on the proposals
509	509	9 submitted. The Agency shall award a 5-year contract to the
510	510	10 expert or expert consulting firm so selected with
511	511	11 Commission approval.
512	512	12 (b) The experts or expert consulting firms retained by the
513	513	13 Agency shall, as appropriate, prepare procurement plans, and
514	514	14 conduct a competitive procurement process as prescribed in
515	515	15 Section 16-111.5 of the Public Utilities Act, to ensure
516	516	16 adequate, reliable, affordable, efficient, and environmentally
517	517	17 sustainable electric service at the lowest total cost over
518	518	18 time, taking into account any benefits of price stability, for
519	519	19 eligible retail customers of electric utilities that on
520	520	20 December 31, 2005 provided electric service to at least
521	521	21 100,000 customers in the State of Illinois, and for eligible
522	522	22 Illinois retail customers of small multi-jurisdictional
523	523	23 electric utilities that (i) on December 31, 2005 served less
524	524	24 than 100,000 customers in Illinois and (ii) request a
525	525	25 procurement plan for their Illinois jurisdictional load.
526	526	26 (c) Renewable portfolio standard.
527	527
528	528
529	529
530	530
531	531
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533	533
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537	537	1 (1)(A) The Agency shall develop a long-term renewable
538	538	2 resources procurement plan that shall include procurement
539	539	3 programs and competitive procurement events necessary to
540	540	4 meet the goals set forth in this subsection (c). The
541	541	5 initial long-term renewable resources procurement plan
542	542	6 shall be released for comment no later than 160 days after
543	543	7 June 1, 2017 (the effective date of Public Act 99-906).
544	544	8 The Agency shall review, and may revise on an expedited
545	545	9 basis, the long-term renewable resources procurement plan
546	546	10 at least every 2 years, which shall be conducted in
547	547	11 conjunction with the procurement plan under Section
548	548	12 16-111.5 of the Public Utilities Act to the extent
549	549	13 practicable to minimize administrative expense. No later
550	550	14 than 120 days after the effective date of this amendatory
551	551	15 Act of the 103rd General Assembly, the Agency shall
552	552	16 release for comment a revision to the long-term renewable
553	553	17 resources procurement plan, updating elements of the most
554	554	18 recently approved plan as needed to comply with this
555	555	19 amendatory Act of the 103rd General Assembly, and any
556	556	20 long-term renewable resources procurement plan update
557	557	21 published by the Agency but not yet approved by the
558	558	22 Illinois Commerce Commission shall be withdrawn. The
559	559	23 long-term renewable resources procurement plans shall be
560	560	24 subject to review and approval by the Commission under
561	561	25 Section 16-111.5 of the Public Utilities Act.
562	562	26 (B) Subject to subparagraph (F) of this paragraph (1),
563	563
564	564
565	565
566	566
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569	569
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573	573	1 the long-term renewable resources procurement plan shall
574	574	2 attempt to meet the goals for procurement of renewable
575	575	3 energy credits at levels of at least the following overall
576	576	4 percentages: 13% by the 2017 delivery year; increasing by
577	577	5 at least 1.5% each delivery year thereafter to at least
578	578	6 25% by the 2025 delivery year; increasing by at least 3%
579	579	7 each delivery year thereafter to at least 40% by the 2030
580	580	8 delivery year, and continuing at no less than 40% for each
581	581	9 delivery year thereafter. The Agency shall attempt to
582	582	10 procure 50% by delivery year 2040. The Agency shall
583	583	11 determine the annual increase between delivery year 2030
584	584	12 and delivery year 2040, if any, taking into account energy
585	585	13 demand, other energy resources, and other public policy
586	586	14 goals. In the event of a conflict between these goals and
587	587	15 the new wind, new photovoltaic, and hydropower procurement
588	588	16 requirements described in items (i) through (iii) of
589	589	17 subparagraph (C) of this paragraph (1), the long-term plan
590	590	18 shall prioritize compliance with the new wind, new
591	591	19 photovoltaic, and hydropower procurement requirements
592	592	20 described in items (i) through (iii) of subparagraph (C)
593	593	21 of this paragraph (1) over the annual percentage targets
594	594	22 described in this subparagraph (B). The Agency shall not
595	595	23 comply with the annual percentage targets described in
596	596	24 this subparagraph (B) by procuring renewable energy
597	597	25 credits that are unlikely to lead to the development of
598	598	26 new renewable resources or new, modernized, or retooled
599	599
600	600
601	601
602	602
603	603
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605	605
606	606
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608	608	SB1442 - 17 - LRB104 11424 BDA 21512 b
609	609	1 hydropower facilities.
610	610	2 For the delivery year beginning June 1, 2017, the
611	611	3 procurement plan shall attempt to include, subject to the
612	612	4 prioritization outlined in this subparagraph (B),
613	613	5 cost-effective renewable energy resources equal to at
614	614	6 least 13% of each utility's load for eligible retail
615	615	7 customers and 13% of the applicable portion of each
616	616	8 utility's load for retail customers who are not eligible
617	617	9 retail customers, which applicable portion shall equal 50%
618	618	10 of the utility's load for retail customers who are not
619	619	11 eligible retail customers on February 28, 2017.
620	620	12 For the delivery year beginning June 1, 2018, the
621	621	13 procurement plan shall attempt to include, subject to the
622	622	14 prioritization outlined in this subparagraph (B),
623	623	15 cost-effective renewable energy resources equal to at
624	624	16 least 14.5% of each utility's load for eligible retail
625	625	17 customers and 14.5% of the applicable portion of each
626	626	18 utility's load for retail customers who are not eligible
627	627	19 retail customers, which applicable portion shall equal 75%
628	628	20 of the utility's load for retail customers who are not
629	629	21 eligible retail customers on February 28, 2017.
630	630	22 For the delivery year beginning June 1, 2019, and for
631	631	23 each year thereafter, the procurement plans shall attempt
632	632	24 to include, subject to the prioritization outlined in this
633	633	25 subparagraph (B), cost-effective renewable energy
634	634	26 resources equal to a minimum percentage of each utility's
635	635
636	636
637	637
638	638
639	639
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641	641
642	642
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644	644	SB1442 - 18 - LRB104 11424 BDA 21512 b
645	645	1 load for all retail customers as follows: 16% by June 1,
646	646	2 2019; increasing by 1.5% each year thereafter to 25% by
647	647	3 June 1, 2025; and 25% by June 1, 2026; increasing by at
648	648	4 least 3% each delivery year thereafter to at least 40% by
649	649	5 the 2030 delivery year, and continuing at no less than 40%
650	650	6 for each delivery year thereafter. The Agency shall
651	651	7 attempt to procure 50% by delivery year 2040. The Agency
652	652	8 shall determine the annual increase between delivery year
653	653	9 2030 and delivery year 2040, if any, taking into account
654	654	10 energy demand, other energy resources, and other public
655	655	11 policy goals.
656	656	12 For each delivery year, the Agency shall first
657	657	13 recognize each utility's obligations for that delivery
658	658	14 year under existing contracts. Any renewable energy
659	659	15 credits under existing contracts, including renewable
660	660	16 energy credits as part of renewable energy resources,
661	661	17 shall be used to meet the goals set forth in this
662	662	18 subsection (c) for the delivery year.
663	663	19 (C) The long-term renewable resources procurement plan
664	664	20 described in subparagraph (A) of this paragraph (1) shall
665	665	21 include the procurement of renewable energy credits from
666	666	22 new projects pursuant to the following terms:
667	667	23 (i) At least 10,000,000 renewable energy credits
668	668	24 delivered annually by the end of the 2021 delivery
669	669	25 year, and increasing ratably to reach 45,000,000
670	670	26 renewable energy credits delivered annually from new
671	671
672	672
673	673
674	674
675	675
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677	677
678	678
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681	681	1 wind and solar projects by the end of delivery year
682	682	2 2030 such that the goals in subparagraph (B) of this
683	683	3 paragraph (1) are met entirely by procurements of
684	684	4 renewable energy credits from new wind and
685	685	5 photovoltaic projects. Of that amount, to the extent
686	686	6 possible, the Agency shall procure 45% from wind and
687	687	7 hydropower projects and 55% from photovoltaic
688	688	8 projects. Of the amount to be procured from
689	689	9 photovoltaic projects, the Agency shall procure: at
690	690	10 least 50% from solar photovoltaic projects using the
691	691	11 program outlined in subparagraph (K) of this paragraph
692	692	12 (1) from distributed renewable energy generation
693	693	13 devices or community renewable generation projects; at
694	694	14 least 47% from utility-scale solar projects; at least
695	695	15 3% from brownfield site photovoltaic projects that are
696	696	16 not community renewable generation projects. In
697	697	17 addition to the amount of renewable energy credits to
698	698	18 be procured from wind projects, the Agency shall
699	699	19 procure at least 700,000 renewable energy credits,
700	700	20 delivered annually for at least 20 years, from one new
701	701	21 utility-scale offshore wind project.
702	702	22 In developing the long-term renewable resources
703	703	23 procurement plan, the Agency shall consider other
704	704	24 approaches, in addition to competitive procurements,
705	705	25 that can be used to procure renewable energy credits
706	706	26 from brownfield site photovoltaic projects and thereby
707	707
708	708
709	709
710	710
711	711
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713	713
714	714
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717	717	1 help return blighted or contaminated land to
718	718	2 productive use while enhancing public health and the
719	719	3 well-being of Illinois residents, including those in
720	720	4 environmental justice communities, as defined using
721	721	5 existing methodologies and findings used by the Agency
722	722	6 and its Administrator in its Illinois Solar for All
723	723	7 Program. The Agency shall also consider other
724	724	8 approaches, in addition to competitive procurements,
725	725	9 to procure renewable energy credits from new and
726	726	10 existing hydropower facilities to support the
727	727	11 development and maintenance of these facilities. The
728	728	12 Agency shall explore options to convert existing dams
729	729	13 but shall not consider approaches to develop new dams
730	730	14 where they do not already exist.
731	731	15 (ii) In any given delivery year, if forecasted
732	732	16 expenses are less than the maximum budget available
733	733	17 under subparagraph (E) of this paragraph (1), the
734	734	18 Agency shall continue to procure new renewable energy
735	735	19 credits until that budget is exhausted in the manner
736	736	20 outlined in item (i) of this subparagraph (C).
737	737	21 (iii) For purposes of this Section:
738	738	22 "Equity and inclusion plan scoring" means a score
739	739	23 of up to 34 points, determined by the Department of
740	740	24 Commerce and Economic Opportunity's review of an
741	741	25 applicant's ability to demonstrate it has a
742	742	26 comprehensive and detailed equity and inclusion plan
743	743
744	744
745	745
746	746
747	747
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749	749
750	750
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753	753	1 crafted to create opportunities for underrepresented
754	754	2 populations in addition to equity investment eligible
755	755	3 communities.
756	756	4 "Equity investment eligible community" has the
757	757	5 meaning set forth in Section 5-5 of the Energy
758	758	6 Transition Act.
759	759	7 "New utility-scale offshore wind procurement"
760	760	8 means a procurement of renewable energy credits from a
761	761	9 new utility-scale offshore wind project issued by the
762	762	10 Agency.
763	763	11 "New utility-scale offshore wind project" means an
764	764	12 electric generating facility that:
765	765	13 (1) generates electricity using wind;
766	766	14 (2) has a nameplate capacity that is greater
767	767	15 than 150 megawatts;
768	768	16 (3) is sited in the waters of Lake Michigan;
769	769	17 (4) is interconnected to the PJM
770	770	18 Interconnection's regional transmission system;
771	771	19 (5) has a fully executed project labor
772	772	20 agreement with the applicable local building and
773	773	21 construction trades council;
774	774	22 (6) has a comprehensive and detailed equity
775	775	23 and inclusion plan crafted to create opportunities
776	776	24 for underrepresented populations in addition to
777	777	25 equity investment eligible communities; and
778	778	26 (7) has a permit pursuant to the Rivers,
779	779
780	780
781	781
782	782
783	783
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785	785
786	786
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789	789	1 Lakes, and Streams Act from the Department of
790	790	2 Natural Resources for a site that is in a
791	791	3 preferred area pursuant to Section 15 of the Lake
792	792	4 Michigan Wind Energy Act.
793	793	5 "New wind projects" means wind renewable energy
794	794	6 facilities that are energized after June 1, 2017 for
795	795	7 the delivery year commencing June 1, 2017.
796	796	8 "New photovoltaic projects" means photovoltaic
797	797	9 renewable energy facilities that are energized after
798	798	10 June 1, 2017. Photovoltaic projects developed under
799	799	11 Section 1-56 of this Act shall not apply towards the
800	800	12 new photovoltaic project requirements in this
801	801	13 subparagraph (C).
802	802	14 For purposes of calculating whether the Agency has
803	803	15 procured enough new wind and solar renewable energy
804	804	16 credits required by this subparagraph (C), renewable
805	805	17 energy facilities that have a multi-year renewable
806	806	18 energy credit delivery contract with the utility
807	807	19 through at least delivery year 2030 shall be
808	808	20 considered new, however no renewable energy credits
809	809	21 from contracts entered into before June 1, 2021 shall
810	810	22 be used to calculate whether the Agency has procured
811	811	23 the correct proportion of new wind and new solar
812	812	24 contracts described in this subparagraph (C) for
813	813	25 delivery year 2021 and thereafter.
814	814	26 (D) Renewable energy credits shall be cost effective.
815	815
816	816
817	817
818	818
819	819
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821	821
822	822
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825	825	1 For purposes of this subsection (c), "cost effective"
826	826	2 means that the costs of procuring renewable energy
827	827	3 resources do not cause the limit stated in subparagraph
828	828	4 (E) of this paragraph (1) to be exceeded and, for
829	829	5 renewable energy credits procured through a competitive
830	830	6 procurement event, do not exceed benchmarks based on
831	831	7 market prices for like products in the region. For
832	832	8 purposes of this subsection (c), "like products" means
833	833	9 contracts for renewable energy credits from the same or
834	834	10 substantially similar technology, same or substantially
835	835	11 similar vintage (new or existing), the same or
836	836	12 substantially similar quantity, and the same or
837	837	13 substantially similar contract length and structure.
838	838	14 Benchmarks shall reflect development, financing, or
839	839	15 related costs resulting from requirements imposed through
840	840	16 other provisions of State law, including, but not limited
841	841	17 to, requirements in subparagraphs (P) and (Q) of this
842	842	18 paragraph (1) and the Renewable Energy Facilities
843	843	19 Agricultural Impact Mitigation Act. Confidential
844	844	20 benchmarks shall be developed by the procurement
845	845	21 administrator, in consultation with the Commission staff,
846	846	22 Agency staff, and the procurement monitor and shall be
847	847	23 subject to Commission review and approval. If price
848	848	24 benchmarks for like products in the region are not
849	849	25 available, the procurement administrator shall establish
850	850	26 price benchmarks based on publicly available data on
851	851
852	852
853	853
854	854
855	855
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857	857
858	858
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861	861	1 regional technology costs and expected current and future
862	862	2 regional energy prices. The benchmarks in this Section
863	863	3 shall not be used to curtail or otherwise reduce
864	864	4 contractual obligations entered into by or through the
865	865	5 Agency prior to June 1, 2017 (the effective date of Public
866	866	6 Act 99-906).
867	867	7 (E) For purposes of this subsection (c), the required
868	868	8 procurement of cost-effective renewable energy resources
869	869	9 for a particular year commencing prior to June 1, 2017
870	870	10 shall be measured as a percentage of the actual amount of
871	871	11 electricity (megawatt-hours) supplied by the electric
872	872	12 utility to eligible retail customers in the delivery year
873	873	13 ending immediately prior to the procurement, and, for
874	874	14 delivery years commencing on and after June 1, 2017, the
875	875	15 required procurement of cost-effective renewable energy
876	876	16 resources for a particular year shall be measured as a
877	877	17 percentage of the actual amount of electricity
878	878	18 (megawatt-hours) delivered by the electric utility in the
879	879	19 delivery year ending immediately prior to the procurement,
880	880	20 to all retail customers in its service territory. For
881	881	21 purposes of this subsection (c), the amount paid per
882	882	22 kilowatthour means the total amount paid for electric
883	883	23 service expressed on a per kilowatthour basis. For
884	884	24 purposes of this subsection (c), the total amount paid for
885	885	25 electric service includes without limitation amounts paid
886	886	26 for supply, transmission, capacity, distribution,
887	887
888	888
889	889
890	890
891	891
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893	893
894	894
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897	897	1 surcharges, and add-on taxes.
898	898	2 Notwithstanding the requirements of this subsection
899	899	3 (c), the total of renewable energy resources procured
900	900	4 under the procurement plan for any single year shall be
901	901	5 subject to the limitations of this subparagraph (E). Such
902	902	6 procurement shall be reduced for all retail customers
903	903	7 based on the amount necessary to limit the annual
904	904	8 estimated average net increase due to the costs of these
905	905	9 resources included in the amounts paid by eligible retail
906	906	10 customers in connection with electric service to no more
907	907	11 than 4.25% of the amount paid per kilowatthour by those
908	908	12 customers during the year ending May 31, 2009 and to no
909	909	13 more than 4.5% of that amount as of the billing month
910	910	14 following the expected date that a new utility-scale
911	911	15 offshore wind project commences commercial operations and
912	912	16 is expected to begin delivering power to the PJM
913	913	17 Interconnection, LLC transmission grid. The new off-shore
914	914	18 utility-scale wind project must provide notice of the
915	915	19 expected commercial operation date to the Illinois Power
916	916	20 Agency and each electric utility at least 90 days prior to
917	917	21 commencing commercial operation and delivering power to
918	918	22 the PJM Interconnection, LLC transmission grid. To arrive
919	919	23 at a maximum dollar amount of renewable energy resources
920	920	24 to be procured for the particular delivery year, the
921	921	25 resulting per kilowatthour amount shall be applied to the
922	922	26 actual amount of kilowatthours of electricity delivered,
923	923
924	924
925	925
926	926
927	927
928	928	SB1442 - 25 - LRB104 11424 BDA 21512 b
929	929
930	930
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933	933	1 or applicable portion of such amount as specified in
934	934	2 paragraph (1) of this subsection (c), as applicable, by
935	935	3 the electric utility in the delivery year immediately
936	936	4 prior to the procurement to all retail customers in its
937	937	5 service territory. The calculations required by this
938	938	6 subparagraph (E) shall be made only once for each delivery
939	939	7 year at the time that the renewable energy resources are
940	940	8 procured. Once the determination as to the amount of
941	941	9 renewable energy resources to procure is made based on the
942	942	10 calculations set forth in this subparagraph (E) and the
943	943	11 contracts procuring those amounts are executed, no
944	944	12 subsequent rate impact determinations shall be made and no
945	945	13 adjustments to those contract amounts shall be allowed.
946	946	14 All costs incurred under such contracts shall be fully
947	947	15 recoverable by the electric utility as provided in this
948	948	16 Section.
949	949	17 (F) If the limitation on the amount of renewable
950	950	18 energy resources procured in subparagraph (E) of this
951	951	19 paragraph (1) prevents the Agency from meeting all of the
952	952	20 goals in this subsection (c), the Agency's long-term plan
953	953	21 shall prioritize compliance with the requirements of this
954	954	22 subsection (c) regarding renewable energy credits in the
955	955	23 following order:
956	956	24 (i) renewable energy credits under existing
957	957	25 contractual obligations as of June 1, 2021;
958	958	26 (i-5) funding for the Illinois Solar for All
959	959
960	960
961	961
962	962
963	963
964	964	SB1442 - 26 - LRB104 11424 BDA 21512 b
965	965
966	966
967	967	SB1442- 27 -LRB104 11424 BDA 21512 b SB1442 - 27 - LRB104 11424 BDA 21512 b
968	968	SB1442 - 27 - LRB104 11424 BDA 21512 b
969	969	1 Program, as described in subparagraph (O) of this
970	970	2 paragraph (1);
971	971	3 (ii) renewable energy credits necessary to comply
972	972	4 with the new wind and new photovoltaic procurement
973	973	5 requirements described in items (i) through (iii) of
974	974	6 subparagraph (C) of this paragraph (1); and
975	975	7 (iii) renewable energy credits necessary to meet
976	976	8 the remaining requirements of this subsection (c).
977	977	9 (G) The following provisions shall apply to the
978	978	10 Agency's procurement of renewable energy credits under
979	979	11 this subsection (c):
980	980	12 (i) Notwithstanding whether a long-term renewable
981	981	13 resources procurement plan has been approved, the
982	982	14 Agency shall conduct an initial forward procurement
983	983	15 for renewable energy credits from new utility-scale
984	984	16 wind projects within 160 days after June 1, 2017 (the
985	985	17 effective date of Public Act 99-906). For the purposes
986	986	18 of this initial forward procurement, the Agency shall
987	987	19 solicit 15-year contracts for delivery of 1,000,000
988	988	20 renewable energy credits delivered annually from new
989	989	21 utility-scale wind projects to begin delivery on June
990	990	22 1, 2019, if available, but not later than June 1, 2021,
991	991	23 unless the project has delays in the establishment of
992	992	24 an operating interconnection with the applicable
993	993	25 transmission or distribution system as a result of the
994	994	26 actions or inactions of the transmission or
995	995
996	996
997	997
998	998
999	999
1000	1000	SB1442 - 27 - LRB104 11424 BDA 21512 b
1001	1001
1002	1002
1003	1003	SB1442- 28 -LRB104 11424 BDA 21512 b SB1442 - 28 - LRB104 11424 BDA 21512 b
1004	1004	SB1442 - 28 - LRB104 11424 BDA 21512 b
1005	1005	1 distribution provider, or other causes for force
1006	1006	2 majeure as outlined in the procurement contract, in
1007	1007	3 which case, not later than June 1, 2022. Payments to
1008	1008	4 suppliers of renewable energy credits shall commence
1009	1009	5 upon delivery. Renewable energy credits procured under
1010	1010	6 this initial procurement shall be included in the
1011	1011	7 Agency's long-term plan and shall apply to all
1012	1012	8 renewable energy goals in this subsection (c).
1013	1013	9 (ii) Notwithstanding whether a long-term renewable
1014	1014	10 resources procurement plan has been approved, the
1015	1015	11 Agency shall conduct an initial forward procurement
1016	1016	12 for renewable energy credits from new utility-scale
1017	1017	13 solar projects and brownfield site photovoltaic
1018	1018	14 projects within one year after June 1, 2017 (the
1019	1019	15 effective date of Public Act 99-906). For the purposes
1020	1020	16 of this initial forward procurement, the Agency shall
1021	1021	17 solicit 15-year contracts for delivery of 1,000,000
1022	1022	18 renewable energy credits delivered annually from new
1023	1023	19 utility-scale solar projects and brownfield site
1024	1024	20 photovoltaic projects to begin delivery on June 1,
1025	1025	21 2019, if available, but not later than June 1, 2021,
1026	1026	22 unless the project has delays in the establishment of
1027	1027	23 an operating interconnection with the applicable
1028	1028	24 transmission or distribution system as a result of the
1029	1029	25 actions or inactions of the transmission or
1030	1030	26 distribution provider, or other causes for force
1031	1031
1032	1032
1033	1033
1034	1034
1035	1035
1036	1036	SB1442 - 28 - LRB104 11424 BDA 21512 b
1037	1037
1038	1038
1039	1039	SB1442- 29 -LRB104 11424 BDA 21512 b SB1442 - 29 - LRB104 11424 BDA 21512 b
1040	1040	SB1442 - 29 - LRB104 11424 BDA 21512 b
1041	1041	1 majeure as outlined in the procurement contract, in
1042	1042	2 which case, not later than June 1, 2022. The Agency may
1043	1043	3 structure this initial procurement in one or more
1044	1044	4 discrete procurement events. Payments to suppliers of
1045	1045	5 renewable energy credits shall commence upon delivery.
1046	1046	6 Renewable energy credits procured under this initial
1047	1047	7 procurement shall be included in the Agency's
1048	1048	8 long-term plan and shall apply to all renewable energy
1049	1049	9 goals in this subsection (c).
1050	1050	10 (iii) Notwithstanding whether the Commission has
1051	1051	11 approved the periodic long-term renewable resources
1052	1052	12 procurement plan revision described in Section
1053	1053	13 16-111.5 of the Public Utilities Act, the Agency shall
1054	1054	14 conduct at least one subsequent forward procurement
1055	1055	15 for renewable energy credits from new utility-scale
1056	1056	16 wind projects, new utility-scale solar projects, and
1057	1057	17 new brownfield site photovoltaic projects within 240
1058	1058	18 days after the effective date of this amendatory Act
1059	1059	19 of the 102nd General Assembly in quantities necessary
1060	1060	20 to meet the requirements of subparagraph (C) of this
1061	1061	21 paragraph (1) through the delivery year beginning June
1062	1062	22 1, 2021.
1063	1063	23 (iii-5) Notwithstanding whether the Commission has
1064	1064	24 approved the long-term renewable resources procurement
1065	1065	25 plan revision process described in Section 16-111.5 of
1066	1066	26 the Public Utilities Act, the Agency shall conduct at
1067	1067
1068	1068
1069	1069
1070	1070
1071	1071
1072	1072	SB1442 - 29 - LRB104 11424 BDA 21512 b
1073	1073
1074	1074
1075	1075	SB1442- 30 -LRB104 11424 BDA 21512 b SB1442 - 30 - LRB104 11424 BDA 21512 b
1076	1076	SB1442 - 30 - LRB104 11424 BDA 21512 b
1077	1077	1 least one new utility-scale offshore wind procurement
1078	1078	2 within 360 days after the effective date of this
1079	1079	3 amendatory Act of the 104th General Assembly in
1080	1080	4 quantities necessary to meet the requirements
1081	1081	5 described in subparagraph (C) of this paragraph (1) by
1082	1082	6 the end of delivery year 2030.
1083	1083	7 The annual amount spent on any new utility-scale
1084	1084	8 offshore wind procurement shall not exceed 0.25% of
1085	1085	9 the amount paid per kilowatt hour by all eligible
1086	1086	10 retail customers in connection with electric service
1087	1087	11 during the year ending May 31, 2009, and shall be spent
1088	1088	12 only after the new utility-scale offshore wind project
1089	1089	13 commences commercial operations and is delivering
1090	1090	14 power to the PJM Interconnection, LLC transmission
1091	1091	15 grid.
1092	1092	16 Before submitting a proposal to the Agency in
1093	1093	17 response to a new utility-scale offshore wind
1094	1094	18 procurement, an applicant must first submit to the
1095	1095	19 Department of Commerce and Economic Opportunity a
1096	1096	20 separate application for equity and inclusion plan
1097	1097	21 scoring. The Department of Commerce and Economic
1098	1098	22 Opportunity will provide equity and inclusion plan
1099	1099	23 scoring to the Agency upon the Agency's request.
1100	1100	24 In order to award a renewable energy credit
1101	1101	25 contract in a new utility-scale offshore wind
1102	1102	26 procurement, the Agency shall use the following
1103	1103
1104	1104
1105	1105
1106	1106
1107	1107
1108	1108	SB1442 - 30 - LRB104 11424 BDA 21512 b
1109	1109
1110	1110
1111	1111	SB1442- 31 -LRB104 11424 BDA 21512 b SB1442 - 31 - LRB104 11424 BDA 21512 b
1112	1112	SB1442 - 31 - LRB104 11424 BDA 21512 b
1113	1113	1 point-based scoring criteria, totaling 100 points, in
1114	1114	2 evaluating an applicant's proposal:
1115	1115	3 (1) 33 points: attributed to the price
1116	1116	4 submitted in such proposal, with a lower price
1117	1117	5 being more favorable;
1118	1118	6 (2) 33 points: attributed to the overall
1119	1119	7 viability of applicant and its plan to build a new
1120	1120	8 utility-scale offshore wind project, as determined
1121	1121	9 by the Agency using the following criteria
1122	1122	10 establishing that the applicant:
1123	1123	11 (A) has identified and proffered a
1124	1124	12 rationale for a site for its new utility-scale
1125	1125	13 offshore wind project and has a comprehensive
1126	1126	14 plan to develop, construct, own, and operate
1127	1127	15 the project;
1128	1128	16 (B) has experience and knowledge, or any
1129	1129	17 of the applicant's affiliates have experience
1130	1130	18 or knowledge, in owning offshore wind
1131	1131	19 projects;
1132	1132	20 (C) has a fully executed project labor
1133	1133	21 agreement with the applicable local building
1134	1134	22 and construction trades council;
1135	1135	23 (D) has a comprehensive plan to maximize
1136	1136	24 local economic impact and job creation;
1137	1137	25 (E) has submitted a financing plan showing
1138	1138	26 the financial ability to build, own, and
1139	1139
1140	1140
1141	1141
1142	1142
1143	1143
1144	1144	SB1442 - 31 - LRB104 11424 BDA 21512 b
1145	1145
1146	1146
1147	1147	SB1442- 32 -LRB104 11424 BDA 21512 b SB1442 - 32 - LRB104 11424 BDA 21512 b
1148	1148	SB1442 - 32 - LRB104 11424 BDA 21512 b
1149	1149	1 operate a new utility-scale offshore wind
1150	1150	2 project, examples of which may include, but
1151	1151	3 are not limited to: (i) sources of debt; (ii)
1152	1152	4 letters of reference from a commercial bank;
1153	1153	5 or (iii) an equity commitment letter from a
1154	1154	6 parent company;
1155	1155	7 (F) has a comprehensive plan to conduct
1156	1156	8 essential research around the compatibility of
1157	1157	9 offshore wind and the lake ecology and
1158	1158	10 historical lake uses that can become the basis
1159	1159	11 for future decision making around prudent
1160	1160	12 expansion of offshore wind into Lake Michigan;
1161	1161	13 (G) has a plan to mitigate local landward
1162	1162	14 environmental impacts that may otherwise
1163	1163	15 result from construction of a new
1164	1164	16 utility-scale offshore wind project;
1165	1165	17 (H) has a plan to obtain a permit pursuant
1166	1166	18 to the Rivers, Lakes, and Streams Act from the
1167	1167	19 Department of Natural Resources; and
1168	1168	20 (I) fully intends on complying with the
1169	1169	21 Lake Michigan Wind Energy Act and all rules
1170	1170	22 and regulations of the Environmental
1171	1171	23 Protection Agency; and
1172	1172	24 (3) 34 points: attributed to equity and
1173	1173	25 inclusion plan scoring.
1174	1174	26 No renewable energy credit contract shall be
1175	1175
1176	1176
1177	1177
1178	1178
1179	1179
1180	1180	SB1442 - 32 - LRB104 11424 BDA 21512 b
1181	1181
1182	1182
1183	1183	SB1442- 33 -LRB104 11424 BDA 21512 b SB1442 - 33 - LRB104 11424 BDA 21512 b
1184	1184	SB1442 - 33 - LRB104 11424 BDA 21512 b
1185	1185	1 awarded to an applicant who fails to receive at least
1186	1186	2 75 points. The Agency shall ensure that a renewable
1187	1187	3 energy credit contract awarded to a new utility-scale
1188	1188	4 offshore wind project contains a project
1189	1189	5 decommissioning requirement.
1190	1190	6 (iv) Notwithstanding whether the Commission has
1191	1191	7 approved the periodic long-term renewable resources
1192	1192	8 procurement plan revision described in Section
1193	1193	9 16-111.5 of the Public Utilities Act, the Agency shall
1194	1194	10 open capacity for each category in the Adjustable
1195	1195	11 Block program within 90 days after the effective date
1196	1196	12 of this amendatory Act of the 102nd General Assembly
1197	1197	13 manner:
1198	1198	14 (1) The Agency shall open the first block of
1199	1199	15 annual capacity for the category described in item
1200	1200	16 (i) of subparagraph (K) of this paragraph (1). The
1201	1201	17 first block of annual capacity for item (i) shall
1202	1202	18 be for at least 75 megawatts of total nameplate
1203	1203	19 capacity. The price of the renewable energy credit
1204	1204	20 for this block of capacity shall be 4% less than
1205	1205	21 the price of the last open block in this category.
1206	1206	22 Projects on a waitlist shall be awarded contracts
1207	1207	23 first in the order in which they appear on the
1208	1208	24 waitlist. Notwithstanding anything to the
1209	1209	25 contrary, for those renewable energy credits that
1210	1210	26 qualify and are procured under this subitem (1) of
1211	1211
1212	1212
1213	1213
1214	1214
1215	1215
1216	1216	SB1442 - 33 - LRB104 11424 BDA 21512 b
1217	1217
1218	1218
1219	1219	SB1442- 34 -LRB104 11424 BDA 21512 b SB1442 - 34 - LRB104 11424 BDA 21512 b
1220	1220	SB1442 - 34 - LRB104 11424 BDA 21512 b
1221	1221	1 this item (iv), the renewable energy credit
1222	1222	2 delivery contract value shall be paid in full,
1223	1223	3 based on the estimated generation during the first
1224	1224	4 15 years of operation, by the contracting
1225	1225	5 utilities at the time that the facility producing
1226	1226	6 the renewable energy credits is interconnected at
1227	1227	7 the distribution system level of the utility and
1228	1228	8 verified as energized and in compliance by the
1229	1229	9 Program Administrator. The electric utility shall
1230	1230	10 receive and retire all renewable energy credits
1231	1231	11 generated by the project for the first 15 years of
1232	1232	12 operation. Renewable energy credits generated by
1233	1233	13 the project thereafter shall not be transferred
1234	1234	14 under the renewable energy credit delivery
1235	1235	15 contract with the counterparty electric utility.
1236	1236	16 (2) The Agency shall open the first block of
1237	1237	17 annual capacity for the category described in item
1238	1238	18 (ii) of subparagraph (K) of this paragraph (1).
1239	1239	19 The first block of annual capacity for item (ii)
1240	1240	20 shall be for at least 75 megawatts of total
1241	1241	21 nameplate capacity.
1242	1242	22 (A) The price of the renewable energy
1243	1243	23 credit for any project on a waitlist for this
1244	1244	24 category before the opening of this block
1245	1245	25 shall be 4% less than the price of the last
1246	1246	26 open block in this category. Projects on the
1247	1247
1248	1248
1249	1249
1250	1250
1251	1251
1252	1252	SB1442 - 34 - LRB104 11424 BDA 21512 b
1253	1253
1254	1254
1255	1255	SB1442- 35 -LRB104 11424 BDA 21512 b SB1442 - 35 - LRB104 11424 BDA 21512 b
1256	1256	SB1442 - 35 - LRB104 11424 BDA 21512 b
1257	1257	1 waitlist shall be awarded contracts first in
1258	1258	2 the order in which they appear on the
1259	1259	3 waitlist. Any projects that are less than or
1260	1260	4 equal to 25 kilowatts in size on the waitlist
1261	1261	5 for this capacity shall be moved to the
1262	1262	6 waitlist for paragraph (1) of this item (iv).
1263	1263	7 Notwithstanding anything to the contrary,
1264	1264	8 projects that were on the waitlist prior to
1265	1265	9 opening of this block shall not be required to
1266	1266	10 be in compliance with the requirements of
1267	1267	11 subparagraph (Q) of this paragraph (1) of this
1268	1268	12 subsection (c). Notwithstanding anything to
1269	1269	13 the contrary, for those renewable energy
1270	1270	14 credits procured from projects that were on
1271	1271	15 the waitlist for this category before the
1272	1272	16 opening of this block 20% of the renewable
1273	1273	17 energy credit delivery contract value, based
1274	1274	18 on the estimated generation during the first
1275	1275	19 15 years of operation, shall be paid by the
1276	1276	20 contracting utilities at the time that the
1277	1277	21 facility producing the renewable energy
1278	1278	22 credits is interconnected at the distribution
1279	1279	23 system level of the utility and verified as
1280	1280	24 energized by the Program Administrator. The
1281	1281	25 remaining portion shall be paid ratably over
1282	1282	26 the subsequent 4-year period. The electric
1283	1283
1284	1284
1285	1285
1286	1286
1287	1287
1288	1288	SB1442 - 35 - LRB104 11424 BDA 21512 b
1289	1289
1290	1290
1291	1291	SB1442- 36 -LRB104 11424 BDA 21512 b SB1442 - 36 - LRB104 11424 BDA 21512 b
1292	1292	SB1442 - 36 - LRB104 11424 BDA 21512 b
1293	1293	1 utility shall receive and retire all renewable
1294	1294	2 energy credits generated by the project during
1295	1295	3 the first 15 years of operation. Renewable
1296	1296	4 energy credits generated by the project
1297	1297	5 thereafter shall not be transferred under the
1298	1298	6 renewable energy credit delivery contract with
1299	1299	7 the counterparty electric utility.
1300	1300	8 (B) The price of renewable energy credits
1301	1301	9 for any project not on the waitlist for this
1302	1302	10 category before the opening of the block shall
1303	1303	11 be determined and published by the Agency.
1304	1304	12 Projects not on a waitlist as of the opening
1305	1305	13 of this block shall be subject to the
1306	1306	14 requirements of subparagraph (Q) of this
1307	1307	15 paragraph (1), as applicable. Projects not on
1308	1308	16 a waitlist as of the opening of this block
1309	1309	17 shall be subject to the contract provisions
1310	1310	18 outlined in item (iii) of subparagraph (L) of
1311	1311	19 this paragraph (1). The Agency shall strive to
1312	1312	20 publish updated prices and an updated
1313	1313	21 renewable energy credit delivery contract as
1314	1314	22 quickly as possible.
1315	1315	23 (3) For opening the first 2 blocks of annual
1316	1316	24 capacity for projects participating in item (iii)
1317	1317	25 of subparagraph (K) of paragraph (1) of subsection
1318	1318	26 (c), projects shall be selected exclusively from
1319	1319
1320	1320
1321	1321
1322	1322
1323	1323
1324	1324	SB1442 - 36 - LRB104 11424 BDA 21512 b
1325	1325
1326	1326
1327	1327	SB1442- 37 -LRB104 11424 BDA 21512 b SB1442 - 37 - LRB104 11424 BDA 21512 b
1328	1328	SB1442 - 37 - LRB104 11424 BDA 21512 b
1329	1329	1 those projects on the ordinal waitlists of
1330	1330	2 community renewable generation projects
1331	1331	3 established by the Agency based on the status of
1332	1332	4 those ordinal waitlists as of December 31, 2020,
1333	1333	5 and only those projects previously determined to
1334	1334	6 be eligible for the Agency's April 2019 community
1335	1335	7 solar project selection process.
1336	1336	8 The first 2 blocks of annual capacity for item
1337	1337	9 (iii) shall be for 250 megawatts of total
1338	1338	10 nameplate capacity, with both blocks opening
1339	1339	11 simultaneously under the schedule outlined in the
1340	1340	12 paragraphs below. Projects shall be selected as
1341	1341	13 follows:
1342	1342	14 (A) The geographic balance of selected
1343	1343	15 projects shall follow the Group classification
1344	1344	16 found in the Agency's Revised Long-Term
1345	1345	17 Renewable Resources Procurement Plan, with 70%
1346	1346	18 of capacity allocated to projects on the Group
1347	1347	19 B waitlist and 30% of capacity allocated to
1348	1348	20 projects on the Group A waitlist.
1349	1349	21 (B) Contract awards for waitlisted
1350	1350	22 projects shall be allocated proportionate to
1351	1351	23 the total nameplate capacity amount across
1352	1352	24 both ordinal waitlists associated with that
1353	1353	25 applicant firm or its affiliates, subject to
1354	1354	26 the following conditions.
1355	1355
1356	1356
1357	1357
1358	1358
1359	1359
1360	1360	SB1442 - 37 - LRB104 11424 BDA 21512 b
1361	1361
1362	1362
1363	1363	SB1442- 38 -LRB104 11424 BDA 21512 b SB1442 - 38 - LRB104 11424 BDA 21512 b
1364	1364	SB1442 - 38 - LRB104 11424 BDA 21512 b
1365	1365	1 (i) Each applicant firm having a
1366	1366	2 waitlisted project eligible for selection
1367	1367	3 shall receive no less than 500 kilowatts
1368	1368	4 in awarded capacity across all groups, and
1369	1369	5 no approved vendor may receive more than
1370	1370	6 20% of each Group's waitlist allocation.
1371	1371	7 (ii) Each applicant firm, upon
1372	1372	8 receiving an award of program capacity
1373	1373	9 proportionate to its waitlisted capacity,
1374	1374	10 may then determine which waitlisted
1375	1375	11 projects it chooses to be selected for a
1376	1376	12 contract award up to that capacity amount.
1377	1377	13 (iii) Assuming all other program
1378	1378	14 requirements are met, applicant firms may
1379	1379	15 adjust the nameplate capacity of applicant
1380	1380	16 projects without losing waitlist
1381	1381	17 eligibility, so long as no project is
1382	1382	18 greater than 2,000 kilowatts in size.
1383	1383	19 (iv) Assuming all other program
1384	1384	20 requirements are met, applicant firms may
1385	1385	21 adjust the expected production associated
1386	1386	22 with applicant projects, subject to
1387	1387	23 verification by the Program Administrator.
1388	1388	24 (C) After a review of affiliate
1389	1389	25 information and the current ordinal waitlists,
1390	1390	26 the Agency shall announce the nameplate
1391	1391
1392	1392
1393	1393
1394	1394
1395	1395
1396	1396	SB1442 - 38 - LRB104 11424 BDA 21512 b
1397	1397
1398	1398
1399	1399	SB1442- 39 -LRB104 11424 BDA 21512 b SB1442 - 39 - LRB104 11424 BDA 21512 b
1400	1400	SB1442 - 39 - LRB104 11424 BDA 21512 b
1401	1401	1 capacity award amounts associated with
1402	1402	2 applicant firms no later than 90 days after
1403	1403	3 the effective date of this amendatory Act of
1404	1404	4 the 102nd General Assembly.
1405	1405	5 (D) Applicant firms shall submit their
1406	1406	6 portfolio of projects used to satisfy those
1407	1407	7 contract awards no less than 90 days after the
1408	1408	8 Agency's announcement. The total nameplate
1409	1409	9 capacity of all projects used to satisfy that
1410	1410	10 portfolio shall be no greater than the
1411	1411	11 Agency's nameplate capacity award amount
1412	1412	12 associated with that applicant firm. An
1413	1413	13 applicant firm may decline, in whole or in
1414	1414	14 part, its nameplate capacity award without
1415	1415	15 penalty, with such unmet capacity rolled over
1416	1416	16 to the next block opening for project
1417	1417	17 selection under item (iii) of subparagraph (K)
1418	1418	18 of this subsection (c). Any projects not
1419	1419	19 included in an applicant firm's portfolio may
1420	1420	20 reapply without prejudice upon the next block
1421	1421	21 reopening for project selection under item
1422	1422	22 (iii) of subparagraph (K) of this subsection
1423	1423	23 (c).
1424	1424	24 (E) The renewable energy credit delivery
1425	1425	25 contract shall be subject to the contract and
1426	1426	26 payment terms outlined in item (iv) of
1427	1427
1428	1428
1429	1429
1430	1430
1431	1431
1432	1432	SB1442 - 39 - LRB104 11424 BDA 21512 b
1433	1433
1434	1434
1435	1435	SB1442- 40 -LRB104 11424 BDA 21512 b SB1442 - 40 - LRB104 11424 BDA 21512 b
1436	1436	SB1442 - 40 - LRB104 11424 BDA 21512 b
1437	1437	1 subparagraph (L) of this subsection (c).
1438	1438	2 Contract instruments used for this
1439	1439	3 subparagraph shall contain the following
1440	1440	4 terms:
1441	1441	5 (i) Renewable energy credit prices
1442	1442	6 shall be fixed, without further adjustment
1443	1443	7 under any other provision of this Act or
1444	1444	8 for any other reason, at 10% lower than
1445	1445	9 prices applicable to the last open block
1446	1446	10 for this category, inclusive of any adders
1447	1447	11 available for achieving a minimum of 50%
1448	1448	12 of subscribers to the project's nameplate
1449	1449	13 capacity being residential or small
1450	1450	14 commercial customers with subscriptions of
1451	1451	15 below 25 kilowatts in size;
1452	1452	16 (ii) A requirement that a minimum of
1453	1453	17 50% of subscribers to the project's
1454	1454	18 nameplate capacity be residential or small
1455	1455	19 commercial customers with subscriptions of
1456	1456	20 below 25 kilowatts in size;
1457	1457	21 (iii) Permission for the ability of a
1458	1458	22 contract holder to substitute projects
1459	1459	23 with other waitlisted projects without
1460	1460	24 penalty should a project receive a
1461	1461	25 non-binding estimate of costs to construct
1462	1462	26 the interconnection facilities and any
1463	1463
1464	1464
1465	1465
1466	1466
1467	1467
1468	1468	SB1442 - 40 - LRB104 11424 BDA 21512 b
1469	1469
1470	1470
1471	1471	SB1442- 41 -LRB104 11424 BDA 21512 b SB1442 - 41 - LRB104 11424 BDA 21512 b
1472	1472	SB1442 - 41 - LRB104 11424 BDA 21512 b
1473	1473	1 required distribution upgrades associated
1474	1474	2 with that project of greater than 30 cents
1475	1475	3 per watt AC of that project's nameplate
1476	1476	4 capacity. In developing the applicable
1477	1477	5 contract instrument, the Agency may
1478	1478	6 consider whether other circumstances
1479	1479	7 outside of the control of the applicant
1480	1480	8 firm should also warrant project
1481	1481	9 substitution rights.
1482	1482	10 The Agency shall publish a finalized
1483	1483	11 updated renewable energy credit delivery
1484	1484	12 contract developed consistent with these terms
1485	1485	13 and conditions no less than 30 days before
1486	1486	14 applicant firms must submit their portfolio of
1487	1487	15 projects pursuant to item (D).
1488	1488	16 (F) To be eligible for an award, the
1489	1489	17 applicant firm shall certify that not less
1490	1490	18 than prevailing wage, as determined pursuant
1491	1491	19 to the Illinois Prevailing Wage Act, was or
1492	1492	20 will be paid to employees who are engaged in
1493	1493	21 construction activities associated with a
1494	1494	22 selected project.
1495	1495	23 (4) The Agency shall open the first block of
1496	1496	24 annual capacity for the category described in item
1497	1497	25 (iv) of subparagraph (K) of this paragraph (1).
1498	1498	26 The first block of annual capacity for item (iv)
1499	1499
1500	1500
1501	1501
1502	1502
1503	1503
1504	1504	SB1442 - 41 - LRB104 11424 BDA 21512 b
1505	1505
1506	1506
1507	1507	SB1442- 42 -LRB104 11424 BDA 21512 b SB1442 - 42 - LRB104 11424 BDA 21512 b
1508	1508	SB1442 - 42 - LRB104 11424 BDA 21512 b
1509	1509	1 shall be for at least 50 megawatts of total
1510	1510	2 nameplate capacity. Renewable energy credit prices
1511	1511	3 shall be fixed, without further adjustment under
1512	1512	4 any other provision of this Act or for any other
1513	1513	5 reason, at the price in the last open block in the
1514	1514	6 category described in item (ii) of subparagraph
1515	1515	7 (K) of this paragraph (1). Pricing for future
1516	1516	8 blocks of annual capacity for this category may be
1517	1517	9 adjusted in the Agency's second revision to its
1518	1518	10 Long-Term Renewable Resources Procurement Plan.
1519	1519	11 Projects in this category shall be subject to the
1520	1520	12 contract terms outlined in item (iv) of
1521	1521	13 subparagraph (L) of this paragraph (1).
1522	1522	14 (5) The Agency shall open the equivalent of 2
1523	1523	15 years of annual capacity for the category
1524	1524	16 described in item (v) of subparagraph (K) of this
1525	1525	17 paragraph (1). The first block of annual capacity
1526	1526	18 for item (v) shall be for at least 10 megawatts of
1527	1527	19 total nameplate capacity. Notwithstanding the
1528	1528	20 provisions of item (v) of subparagraph (K) of this
1529	1529	21 paragraph (1), for the purpose of this initial
1530	1530	22 block, the agency shall accept new project
1531	1531	23 applications intended to increase the diversity of
1532	1532	24 areas hosting community solar projects, the
1533	1533	25 business models of projects, and the size of
1534	1534	26 projects, as described by the Agency in its
1535	1535
1536	1536
1537	1537
1538	1538
1539	1539
1540	1540	SB1442 - 42 - LRB104 11424 BDA 21512 b
1541	1541
1542	1542
1543	1543	SB1442- 43 -LRB104 11424 BDA 21512 b SB1442 - 43 - LRB104 11424 BDA 21512 b
1544	1544	SB1442 - 43 - LRB104 11424 BDA 21512 b
1545	1545	1 long-term renewable resources procurement plan
1546	1546	2 that is approved as of the effective date of this
1547	1547	3 amendatory Act of the 102nd General Assembly.
1548	1548	4 Projects in this category shall be subject to the
1549	1549	5 contract terms outlined in item (iii) of
1550	1550	6 subsection (L) of this paragraph (1).
1551	1551	7 (6) The Agency shall open the first blocks of
1552	1552	8 annual capacity for the category described in item
1553	1553	9 (vi) of subparagraph (K) of this paragraph (1),
1554	1554	10 with allocations of capacity within the block
1555	1555	11 generally matching the historical share of block
1556	1556	12 capacity allocated between the category described
1557	1557	13 in items (i) and (ii) of subparagraph (K) of this
1558	1558	14 paragraph (1). The first two blocks of annual
1559	1559	15 capacity for item (vi) shall be for at least 75
1560	1560	16 megawatts of total nameplate capacity. The price
1561	1561	17 of renewable energy credits for the blocks of
1562	1562	18 capacity shall be 4% less than the price of the
1563	1563	19 last open blocks in the categories described in
1564	1564	20 items (i) and (ii) of subparagraph (K) of this
1565	1565	21 paragraph (1). Pricing for future blocks of annual
1566	1566	22 capacity for this category may be adjusted in the
1567	1567	23 Agency's second revision to its Long-Term
1568	1568	24 Renewable Resources Procurement Plan. Projects in
1569	1569	25 this category shall be subject to the applicable
1570	1570	26 contract terms outlined in items (ii) and (iii) of
1571	1571
1572	1572
1573	1573
1574	1574
1575	1575
1576	1576	SB1442 - 43 - LRB104 11424 BDA 21512 b
1577	1577
1578	1578
1579	1579	SB1442- 44 -LRB104 11424 BDA 21512 b SB1442 - 44 - LRB104 11424 BDA 21512 b
1580	1580	SB1442 - 44 - LRB104 11424 BDA 21512 b
1581	1581	1 subparagraph (L) of this paragraph (1).
1582	1582	2 (v) Upon the effective date of this amendatory Act
1583	1583	3 of the 102nd General Assembly, for all competitive
1584	1584	4 procurements and any procurements of renewable energy
1585	1585	5 credit from new utility-scale wind and new
1586	1586	6 utility-scale photovoltaic projects, the Agency shall
1587	1587	7 procure indexed renewable energy credits and direct
1588	1588	8 respondents to offer a strike price.
1589	1589	9 (1) The purchase price of the indexed
1590	1590	10 renewable energy credit payment shall be
1591	1591	11 calculated for each settlement period. That
1592	1592	12 payment, for any settlement period, shall be equal
1593	1593	13 to the difference resulting from subtracting the
1594	1594	14 strike price from the index price for that
1595	1595	15 settlement period. If this difference results in a
1596	1596	16 negative number, the indexed REC counterparty
1597	1597	17 shall owe the seller the absolute value multiplied
1598	1598	18 by the quantity of energy produced in the relevant
1599	1599	19 settlement period. If this difference results in a
1600	1600	20 positive number, the seller shall owe the indexed
1601	1601	21 REC counterparty this amount multiplied by the
1602	1602	22 quantity of energy produced in the relevant
1603	1603	23 settlement period.
1604	1604	24 (2) Parties shall cash settle every month,
1605	1605	25 summing up all settlements (both positive and
1606	1606	26 negative, if applicable) for the prior month.
1607	1607
1608	1608
1609	1609
1610	1610
1611	1611
1612	1612	SB1442 - 44 - LRB104 11424 BDA 21512 b
1613	1613
1614	1614
1615	1615	SB1442- 45 -LRB104 11424 BDA 21512 b SB1442 - 45 - LRB104 11424 BDA 21512 b
1616	1616	SB1442 - 45 - LRB104 11424 BDA 21512 b
1617	1617	1 (3) To ensure funding in the annual budget
1618	1618	2 established under subparagraph (E) for indexed
1619	1619	3 renewable energy credit procurements for each year
1620	1620	4 of the term of such contracts, which must have a
1621	1621	5 minimum tenure of 20 calendar years, the
1622	1622	6 procurement administrator, Agency, Commission
1623	1623	7 staff, and procurement monitor shall quantify the
1624	1624	8 annual cost of the contract by utilizing an
1625	1625	9 industry-standard, third-party forward price curve
1626	1626	10 for energy at the appropriate hub or load zone,
1627	1627	11 including the estimated magnitude and timing of
1628	1628	12 the price effects related to federal carbon
1629	1629	13 controls. Each forward price curve shall contain a
1630	1630	14 specific value of the forecasted market price of
1631	1631	15 electricity for each annual delivery year of the
1632	1632	16 contract. For procurement planning purposes, the
1633	1633	17 impact on the annual budget for the cost of
1634	1634	18 indexed renewable energy credits for each delivery
1635	1635	19 year shall be determined as the expected annual
1636	1636	20 contract expenditure for that year, equaling the
1637	1637	21 difference between (i) the sum across all relevant
1638	1638	22 contracts of the applicable strike price
1639	1639	23 multiplied by contract quantity and (ii) the sum
1640	1640	24 across all relevant contracts of the forward price
1641	1641	25 curve for the applicable load zone for that year
1642	1642	26 multiplied by contract quantity. The contracting
1643	1643
1644	1644
1645	1645
1646	1646
1647	1647
1648	1648	SB1442 - 45 - LRB104 11424 BDA 21512 b
1649	1649
1650	1650
1651	1651	SB1442- 46 -LRB104 11424 BDA 21512 b SB1442 - 46 - LRB104 11424 BDA 21512 b
1652	1652	SB1442 - 46 - LRB104 11424 BDA 21512 b
1653	1653	1 utility shall not assume an obligation in excess
1654	1654	2 of the estimated annual cost of the contracts for
1655	1655	3 indexed renewable energy credits. Forward curves
1656	1656	4 shall be revised on an annual basis as updated
1657	1657	5 forward price curves are released and filed with
1658	1658	6 the Commission in the proceeding approving the
1659	1659	7 Agency's most recent long-term renewable resources
1660	1660	8 procurement plan. If the expected contract spend
1661	1661	9 is higher or lower than the total quantity of
1662	1662	10 contracts multiplied by the forward price curve
1663	1663	11 value for that year, the forward price curve shall
1664	1664	12 be updated by the procurement administrator, in
1665	1665	13 consultation with the Agency, Commission staff,
1666	1666	14 and procurement monitors, using then-currently
1667	1667	15 available price forecast data and additional
1668	1668	16 budget dollars shall be obligated or reobligated
1669	1669	17 as appropriate.
1670	1670	18 (4) To ensure that indexed renewable energy
1671	1671	19 credit prices remain predictable and affordable,
1672	1672	20 the Agency may consider the institution of a price
1673	1673	21 collar on REC prices paid under indexed renewable
1674	1674	22 energy credit procurements establishing floor and
1675	1675	23 ceiling REC prices applicable to indexed REC
1676	1676	24 contract prices. Any price collars applicable to
1677	1677	25 indexed REC procurements shall be proposed by the
1678	1678	26 Agency through its long-term renewable resources
1679	1679
1680	1680
1681	1681
1682	1682
1683	1683
1684	1684	SB1442 - 46 - LRB104 11424 BDA 21512 b
1685	1685
1686	1686
1687	1687	SB1442- 47 -LRB104 11424 BDA 21512 b SB1442 - 47 - LRB104 11424 BDA 21512 b
1688	1688	SB1442 - 47 - LRB104 11424 BDA 21512 b
1689	1689	1 procurement plan.
1690	1690	2 (vi) All procurements under this subparagraph (G),
1691	1691	3 including the procurement of renewable energy credits
1692	1692	4 from hydropower facilities, shall comply with the
1693	1693	5 geographic requirements in subparagraph (I) of this
1694	1694	6 paragraph (1) and shall follow the procurement
1695	1695	7 processes and procedures described in this Section and
1696	1696	8 Section 16-111.5 of the Public Utilities Act to the
1697	1697	9 extent practicable, and these processes and procedures
1698	1698	10 may be expedited to accommodate the schedule
1699	1699	11 established by this subparagraph (G).
1700	1700	12 (vii) On and after the effective date of this
1701	1701	13 amendatory Act of the 103rd General Assembly, for all
1702	1702	14 procurements of renewable energy credits from
1703	1703	15 hydropower facilities, the Agency shall establish
1704	1704	16 contract terms designed to optimize existing
1705	1705	17 hydropower facilities through modernization or
1706	1706	18 retooling and establish new hydropower facilities at
1707	1707	19 existing dams. Procurements made under this item (vii)
1708	1708	20 shall prioritize projects located in designated
1709	1709	21 environmental justice communities, as defined in
1710	1710	22 subsection (b) of Section 1-56 of this Act, or in
1711	1711	23 projects located in units of local government with
1712	1712	24 median incomes that do not exceed 82% of the median
1713	1713	25 income of the State.
1714	1714	26 (H) The procurement of renewable energy resources for
1715	1715
1716	1716
1717	1717
1718	1718
1719	1719
1720	1720	SB1442 - 47 - LRB104 11424 BDA 21512 b
1721	1721
1722	1722
1723	1723	SB1442- 48 -LRB104 11424 BDA 21512 b SB1442 - 48 - LRB104 11424 BDA 21512 b
1724	1724	SB1442 - 48 - LRB104 11424 BDA 21512 b
1725	1725	1 a given delivery year shall be reduced as described in
1726	1726	2 this subparagraph (H) if an alternative retail electric
1727	1727	3 supplier meets the requirements described in this
1728	1728	4 subparagraph (H).
1729	1729	5 (i) Within 45 days after June 1, 2017 (the
1730	1730	6 effective date of Public Act 99-906), an alternative
1731	1731	7 retail electric supplier or its successor shall submit
1732	1732	8 an informational filing to the Illinois Commerce
1733	1733	9 Commission certifying that, as of December 31, 2015,
1734	1734	10 the alternative retail electric supplier owned one or
1735	1735	11 more electric generating facilities that generates
1736	1736	12 renewable energy resources as defined in Section 1-10
1737	1737	13 of this Act, provided that such facilities are not
1738	1738	14 powered by wind or photovoltaics, and the facilities
1739	1739	15 generate one renewable energy credit for each
1740	1740	16 megawatthour of energy produced from the facility.
1741	1741	17 The informational filing shall identify each
1742	1742	18 facility that was eligible to satisfy the alternative
1743	1743	19 retail electric supplier's obligations under Section
1744	1744	20 16-115D of the Public Utilities Act as described in
1745	1745	21 this item (i).
1746	1746	22 (ii) For a given delivery year, the alternative
1747	1747	23 retail electric supplier may elect to supply its
1748	1748	24 retail customers with renewable energy credits from
1749	1749	25 the facility or facilities described in item (i) of
1750	1750	26 this subparagraph (H) that continue to be owned by the
1751	1751
1752	1752
1753	1753
1754	1754
1755	1755
1756	1756	SB1442 - 48 - LRB104 11424 BDA 21512 b
1757	1757
1758	1758
1759	1759	SB1442- 49 -LRB104 11424 BDA 21512 b SB1442 - 49 - LRB104 11424 BDA 21512 b
1760	1760	SB1442 - 49 - LRB104 11424 BDA 21512 b
1761	1761	1 alternative retail electric supplier.
1762	1762	2 (iii) The alternative retail electric supplier
1763	1763	3 shall notify the Agency and the applicable utility, no
1764	1764	4 later than February 28 of the year preceding the
1765	1765	5 applicable delivery year or 15 days after June 1, 2017
1766	1766	6 (the effective date of Public Act 99-906), whichever
1767	1767	7 is later, of its election under item (ii) of this
1768	1768	8 subparagraph (H) to supply renewable energy credits to
1769	1769	9 retail customers of the utility. Such election shall
1770	1770	10 identify the amount of renewable energy credits to be
1771	1771	11 supplied by the alternative retail electric supplier
1772	1772	12 to the utility's retail customers and the source of
1773	1773	13 the renewable energy credits identified in the
1774	1774	14 informational filing as described in item (i) of this
1775	1775	15 subparagraph (H), subject to the following
1776	1776	16 limitations:
1777	1777	17 For the delivery year beginning June 1, 2018,
1778	1778	18 the maximum amount of renewable energy credits to
1779	1779	19 be supplied by an alternative retail electric
1780	1780	20 supplier under this subparagraph (H) shall be 68%
1781	1781	21 multiplied by 25% multiplied by 14.5% multiplied
1782	1782	22 by the amount of metered electricity
1783	1783	23 (megawatt-hours) delivered by the alternative
1784	1784	24 retail electric supplier to Illinois retail
1785	1785	25 customers during the delivery year ending May 31,
1786	1786	26 2016.
1787	1787
1788	1788
1789	1789
1790	1790
1791	1791
1792	1792	SB1442 - 49 - LRB104 11424 BDA 21512 b
1793	1793
1794	1794
1795	1795	SB1442- 50 -LRB104 11424 BDA 21512 b SB1442 - 50 - LRB104 11424 BDA 21512 b
1796	1796	SB1442 - 50 - LRB104 11424 BDA 21512 b
1797	1797	1 For delivery years beginning June 1, 2019 and
1798	1798	2 each year thereafter, the maximum amount of
1799	1799	3 renewable energy credits to be supplied by an
1800	1800	4 alternative retail electric supplier under this
1801	1801	5 subparagraph (H) shall be 68% multiplied by 50%
1802	1802	6 multiplied by 16% multiplied by the amount of
1803	1803	7 metered electricity (megawatt-hours) delivered by
1804	1804	8 the alternative retail electric supplier to
1805	1805	9 Illinois retail customers during the delivery year
1806	1806	10 ending May 31, 2016, provided that the 16% value
1807	1807	11 shall increase by 1.5% each delivery year
1808	1808	12 thereafter to 25% by the delivery year beginning
1809	1809	13 June 1, 2025, and thereafter the 25% value shall
1810	1810	14 apply to each delivery year.
1811	1811	15 For each delivery year, the total amount of
1812	1812	16 renewable energy credits supplied by all alternative
1813	1813	17 retail electric suppliers under this subparagraph (H)
1814	1814	18 shall not exceed 9% of the Illinois target renewable
1815	1815	19 energy credit quantity. The Illinois target renewable
1816	1816	20 energy credit quantity for the delivery year beginning
1817	1817	21 June 1, 2018 is 14.5% multiplied by the total amount of
1818	1818	22 metered electricity (megawatt-hours) delivered in the
1819	1819	23 delivery year immediately preceding that delivery
1820	1820	24 year, provided that the 14.5% shall increase by 1.5%
1821	1821	25 each delivery year thereafter to 25% by the delivery
1822	1822	26 year beginning June 1, 2025, and thereafter the 25%
1823	1823
1824	1824
1825	1825
1826	1826
1827	1827
1828	1828	SB1442 - 50 - LRB104 11424 BDA 21512 b
1829	1829
1830	1830
1831	1831	SB1442- 51 -LRB104 11424 BDA 21512 b SB1442 - 51 - LRB104 11424 BDA 21512 b
1832	1832	SB1442 - 51 - LRB104 11424 BDA 21512 b
1833	1833	1 value shall apply to each delivery year.
1834	1834	2 If the requirements set forth in items (i) through
1835	1835	3 (iii) of this subparagraph (H) are met, the charges
1836	1836	4 that would otherwise be applicable to the retail
1837	1837	5 customers of the alternative retail electric supplier
1838	1838	6 under paragraph (6) of this subsection (c) for the
1839	1839	7 applicable delivery year shall be reduced by the ratio
1840	1840	8 of the quantity of renewable energy credits supplied
1841	1841	9 by the alternative retail electric supplier compared
1842	1842	10 to that supplier's target renewable energy credit
1843	1843	11 quantity. The supplier's target renewable energy
1844	1844	12 credit quantity for the delivery year beginning June
1845	1845	13 1, 2018 is 14.5% multiplied by the total amount of
1846	1846	14 metered electricity (megawatt-hours) delivered by the
1847	1847	15 alternative retail supplier in that delivery year,
1848	1848	16 provided that the 14.5% shall increase by 1.5% each
1849	1849	17 delivery year thereafter to 25% by the delivery year
1850	1850	18 beginning June 1, 2025, and thereafter the 25% value
1851	1851	19 shall apply to each delivery year.
1852	1852	20 On or before April 1 of each year, the Agency shall
1853	1853	21 annually publish a report on its website that
1854	1854	22 identifies the aggregate amount of renewable energy
1855	1855	23 credits supplied by alternative retail electric
1856	1856	24 suppliers under this subparagraph (H).
1857	1857	25 (I) The Agency shall design its long-term renewable
1858	1858	26 energy procurement plan to maximize the State's interest
1859	1859
1860	1860
1861	1861
1862	1862
1863	1863
1864	1864	SB1442 - 51 - LRB104 11424 BDA 21512 b
1865	1865
1866	1866
1867	1867	SB1442- 52 -LRB104 11424 BDA 21512 b SB1442 - 52 - LRB104 11424 BDA 21512 b
1868	1868	SB1442 - 52 - LRB104 11424 BDA 21512 b
1869	1869	1 in the health, safety, and welfare of its residents,
1870	1870	2 including but not limited to minimizing sulfur dioxide,
1871	1871	3 nitrogen oxide, particulate matter and other pollution
1872	1872	4 that adversely affects public health in this State,
1873	1873	5 increasing fuel and resource diversity in this State,
1874	1874	6 enhancing the reliability and resiliency of the
1875	1875	7 electricity distribution system in this State, meeting
1876	1876	8 goals to limit carbon dioxide emissions under federal or
1877	1877	9 State law, and contributing to a cleaner and healthier
1878	1878	10 environment for the citizens of this State. In order to
1879	1879	11 further these legislative purposes, renewable energy
1880	1880	12 credits shall be eligible to be counted toward the
1881	1881	13 renewable energy requirements of this subsection (c) if
1882	1882	14 they are generated from facilities located in this State.
1883	1883	15 The Agency may qualify renewable energy credits from
1884	1884	16 facilities located in states adjacent to Illinois or
1885	1885	17 renewable energy credits associated with the electricity
1886	1886	18 generated by a utility-scale wind energy facility or
1887	1887	19 utility-scale photovoltaic facility and transmitted by a
1888	1888	20 qualifying direct current project described in subsection
1889	1889	21 (b-5) of Section 8-406 of the Public Utilities Act to a
1890	1890	22 delivery point on the electric transmission grid located
1891	1891	23 in this State or a state adjacent to Illinois, if the
1892	1892	24 generator demonstrates and the Agency determines that the
1893	1893	25 operation of such facility or facilities will help promote
1894	1894	26 the State's interest in the health, safety, and welfare of
1895	1895
1896	1896
1897	1897
1898	1898
1899	1899
1900	1900	SB1442 - 52 - LRB104 11424 BDA 21512 b
1901	1901
1902	1902
1903	1903	SB1442- 53 -LRB104 11424 BDA 21512 b SB1442 - 53 - LRB104 11424 BDA 21512 b
1904	1904	SB1442 - 53 - LRB104 11424 BDA 21512 b
1905	1905	1 its residents based on the public interest criteria
1906	1906	2 described above. For the purposes of this Section,
1907	1907	3 renewable resources that are delivered via a high voltage
1908	1908	4 direct current converter station located in Illinois shall
1909	1909	5 be deemed generated in Illinois at the time and location
1910	1910	6 the energy is converted to alternating current by the high
1911	1911	7 voltage direct current converter station if the high
1912	1912	8 voltage direct current transmission line: (i) after the
1913	1913	9 effective date of this amendatory Act of the 102nd General
1914	1914	10 Assembly, was constructed with a project labor agreement;
1915	1915	11 (ii) is capable of transmitting electricity at 525kv;
1916	1916	12 (iii) has an Illinois converter station located and
1917	1917	13 interconnected in the region of the PJM Interconnection,
1918	1918	14 LLC; (iv) does not operate as a public utility; and (v) if
1919	1919	15 the high voltage direct current transmission line was
1920	1920	16 energized after June 1, 2023. To ensure that the public
1921	1921	17 interest criteria are applied to the procurement and given
1922	1922	18 full effect, the Agency's long-term procurement plan shall
1923	1923	19 describe in detail how each public interest factor shall
1924	1924	20 be considered and weighted for facilities located in
1925	1925	21 states adjacent to Illinois.
1926	1926	22 (J) In order to promote the competitive development of
1927	1927	23 renewable energy resources in furtherance of the State's
1928	1928	24 interest in the health, safety, and welfare of its
1929	1929	25 residents, renewable energy credits shall not be eligible
1930	1930	26 to be counted toward the renewable energy requirements of
1931	1931
1932	1932
1933	1933
1934	1934
1935	1935
1936	1936	SB1442 - 53 - LRB104 11424 BDA 21512 b
1937	1937
1938	1938
1939	1939	SB1442- 54 -LRB104 11424 BDA 21512 b SB1442 - 54 - LRB104 11424 BDA 21512 b
1940	1940	SB1442 - 54 - LRB104 11424 BDA 21512 b
1941	1941	1 this subsection (c) if they are sourced from a generating
1942	1942	2 unit whose costs were being recovered through rates
1943	1943	3 regulated by this State or any other state or states on or
1944	1944	4 after January 1, 2017. Each contract executed to purchase
1945	1945	5 renewable energy credits under this subsection (c) shall
1946	1946	6 provide for the contract's termination if the costs of the
1947	1947	7 generating unit supplying the renewable energy credits
1948	1948	8 subsequently begin to be recovered through rates regulated
1949	1949	9 by this State or any other state or states; and each
1950	1950	10 contract shall further provide that, in that event, the
1951	1951	11 supplier of the credits must return 110% of all payments
1952	1952	12 received under the contract. Amounts returned under the
1953	1953	13 requirements of this subparagraph (J) shall be retained by
1954	1954	14 the utility and all of these amounts shall be used for the
1955	1955	15 procurement of additional renewable energy credits from
1956	1956	16 new wind or new photovoltaic resources as defined in this
1957	1957	17 subsection (c). The long-term plan shall provide that
1958	1958	18 these renewable energy credits shall be procured in the
1959	1959	19 next procurement event.
1960	1960	20 Notwithstanding the limitations of this subparagraph
1961	1961	21 (J), renewable energy credits sourced from generating
1962	1962	22 units that are constructed, purchased, owned, or leased by
1963	1963	23 an electric utility as part of an approved project,
1964	1964	24 program, or pilot under Section 1-56 of this Act shall be
1965	1965	25 eligible to be counted toward the renewable energy
1966	1966	26 requirements of this subsection (c), regardless of how the
1967	1967
1968	1968
1969	1969
1970	1970
1971	1971
1972	1972	SB1442 - 54 - LRB104 11424 BDA 21512 b
1973	1973
1974	1974
1975	1975	SB1442- 55 -LRB104 11424 BDA 21512 b SB1442 - 55 - LRB104 11424 BDA 21512 b
1976	1976	SB1442 - 55 - LRB104 11424 BDA 21512 b
1977	1977	1 costs of these units are recovered. As long as a
1978	1978	2 generating unit or an identifiable portion of a generating
1979	1979	3 unit has not had and does not have its costs recovered
1980	1980	4 through rates regulated by this State or any other state,
1981	1981	5 HVDC renewable energy credits associated with that
1982	1982	6 generating unit or identifiable portion thereof shall be
1983	1983	7 eligible to be counted toward the renewable energy
1984	1984	8 requirements of this subsection (c).
1985	1985	9 (K) The long-term renewable resources procurement plan
1986	1986	10 developed by the Agency in accordance with subparagraph
1987	1987	11 (A) of this paragraph (1) shall include an Adjustable
1988	1988	12 Block program for the procurement of renewable energy
1989	1989	13 credits from new photovoltaic projects that are
1990	1990	14 distributed renewable energy generation devices or new
1991	1991	15 photovoltaic community renewable generation projects. The
1992	1992	16 Adjustable Block program shall be generally designed to
1993	1993	17 provide for the steady, predictable, and sustainable
1994	1994	18 growth of new solar photovoltaic development in Illinois.
1995	1995	19 To this end, the Adjustable Block program shall provide a
1996	1996	20 transparent annual schedule of prices and quantities to
1997	1997	21 enable the photovoltaic market to scale up and for
1998	1998	22 renewable energy credit prices to adjust at a predictable
1999	1999	23 rate over time. The prices set by the Adjustable Block
2000	2000	24 program can be reflected as a set value or as the product
2001	2001	25 of a formula.
2002	2002	26 The Adjustable Block program shall include for each
2003	2003
2004	2004
2005	2005
2006	2006
2007	2007
2008	2008	SB1442 - 55 - LRB104 11424 BDA 21512 b
2009	2009
2010	2010
2011	2011	SB1442- 56 -LRB104 11424 BDA 21512 b SB1442 - 56 - LRB104 11424 BDA 21512 b
2012	2012	SB1442 - 56 - LRB104 11424 BDA 21512 b
2013	2013	1 category of eligible projects for each delivery year: a
2014	2014	2 single block of nameplate capacity, a price for renewable
2015	2015	3 energy credits within that block, and the terms and
2016	2016	4 conditions for securing a spot on a waitlist once the
2017	2017	5 block is fully committed or reserved. Except as outlined
2018	2018	6 below, the waitlist of projects in a given year will carry
2019	2019	7 over to apply to the subsequent year when another block is
2020	2020	8 opened. Only projects energized on or after June 1, 2017
2021	2021	9 shall be eligible for the Adjustable Block program. For
2022	2022	10 each category for each delivery year the Agency shall
2023	2023	11 determine the amount of generation capacity in each block,
2024	2024	12 and the purchase price for each block, provided that the
2025	2025	13 purchase price provided and the total amount of generation
2026	2026	14 in all blocks for all categories shall be sufficient to
2027	2027	15 meet the goals in this subsection (c). The Agency shall
2028	2028	16 strive to issue a single block sized to provide for
2029	2029	17 stability and market growth. The Agency shall establish
2030	2030	18 program eligibility requirements that ensure that projects
2031	2031	19 that enter the program are sufficiently mature to indicate
2032	2032	20 a demonstrable path to completion. The Agency may
2033	2033	21 periodically review its prior decisions establishing the
2034	2034	22 amount of generation capacity in each block, and the
2035	2035	23 purchase price for each block, and may propose, on an
2036	2036	24 expedited basis, changes to these previously set values,
2037	2037	25 including but not limited to redistributing these amounts
2038	2038	26 and the available funds as necessary and appropriate,
2039	2039
2040	2040
2041	2041
2042	2042
2043	2043
2044	2044	SB1442 - 56 - LRB104 11424 BDA 21512 b
2045	2045
2046	2046
2047	2047	SB1442- 57 -LRB104 11424 BDA 21512 b SB1442 - 57 - LRB104 11424 BDA 21512 b
2048	2048	SB1442 - 57 - LRB104 11424 BDA 21512 b
2049	2049	1 subject to Commission approval as part of the periodic
2050	2050	2 plan revision process described in Section 16-111.5 of the
2051	2051	3 Public Utilities Act. The Agency may define different
2052	2052	4 block sizes, purchase prices, or other distinct terms and
2053	2053	5 conditions for projects located in different utility
2054	2054	6 service territories if the Agency deems it necessary to
2055	2055	7 meet the goals in this subsection (c).
2056	2056	8 The Adjustable Block program shall include the
2057	2057	9 following categories in at least the following amounts:
2058	2058	10 (i) At least 20% from distributed renewable energy
2059	2059	11 generation devices with a nameplate capacity of no
2060	2060	12 more than 25 kilowatts.
2061	2061	13 (ii) At least 20% from distributed renewable
2062	2062	14 energy generation devices with a nameplate capacity of
2063	2063	15 more than 25 kilowatts and no more than 5,000
2064	2064	16 kilowatts. The Agency may create sub-categories within
2065	2065	17 this category to account for the differences between
2066	2066	18 projects for small commercial customers, large
2067	2067	19 commercial customers, and public or non-profit
2068	2068	20 customers.
2069	2069	21 (iii) At least 30% from photovoltaic community
2070	2070	22 renewable generation projects. Capacity for this
2071	2071	23 category for the first 2 delivery years after the
2072	2072	24 effective date of this amendatory Act of the 102nd
2073	2073	25 General Assembly shall be allocated to waitlist
2074	2074	26 projects as provided in paragraph (3) of item (iv) of
2075	2075
2076	2076
2077	2077
2078	2078
2079	2079
2080	2080	SB1442 - 57 - LRB104 11424 BDA 21512 b
2081	2081
2082	2082
2083	2083	SB1442- 58 -LRB104 11424 BDA 21512 b SB1442 - 58 - LRB104 11424 BDA 21512 b
2084	2084	SB1442 - 58 - LRB104 11424 BDA 21512 b
2085	2085	1 subparagraph (G). Starting in the third delivery year
2086	2086	2 after the effective date of this amendatory Act of the
2087	2087	3 102nd General Assembly or earlier if the Agency
2088	2088	4 determines there is additional capacity needed for to
2089	2089	5 meet previous delivery year requirements, the
2090	2090	6 following shall apply:
2091	2091	7 (1) the Agency shall select projects on a
2092	2092	8 first-come, first-serve basis, however the Agency
2093	2093	9 may suggest additional methods to prioritize
2094	2094	10 projects that are submitted at the same time;
2095	2095	11 (2) projects shall have subscriptions of 25 kW
2096	2096	12 or less for at least 50% of the facility's
2097	2097	13 nameplate capacity and the Agency shall price the
2098	2098	14 renewable energy credits with that as a factor;
2099	2099	15 (3) projects shall not be colocated with one
2100	2100	16 or more other community renewable generation
2101	2101	17 projects, as defined in the Agency's first revised
2102	2102	18 long-term renewable resources procurement plan
2103	2103	19 approved by the Commission on February 18, 2020,
2104	2104	20 such that the aggregate nameplate capacity exceeds
2105	2105	21 5,000 kilowatts; and
2106	2106	22 (4) projects greater than 2 MW may not apply
2107	2107	23 until after the approval of the Agency's revised
2108	2108	24 Long-Term Renewable Resources Procurement Plan
2109	2109	25 after the effective date of this amendatory Act of
2110	2110	26 the 102nd General Assembly.
2111	2111
2112	2112
2113	2113
2114	2114
2115	2115
2116	2116	SB1442 - 58 - LRB104 11424 BDA 21512 b
2117	2117
2118	2118
2119	2119	SB1442- 59 -LRB104 11424 BDA 21512 b SB1442 - 59 - LRB104 11424 BDA 21512 b
2120	2120	SB1442 - 59 - LRB104 11424 BDA 21512 b
2121	2121	1 (iv) At least 15% from distributed renewable
2122	2122	2 generation devices or photovoltaic community renewable
2123	2123	3 generation projects installed on public school land.
2124	2124	4 The Agency may create subcategories within this
2125	2125	5 category to account for the differences between
2126	2126	6 project size or location. Projects located within
2127	2127	7 environmental justice communities or within
2128	2128	8 Organizational Units that fall within Tier 1 or Tier 2
2129	2129	9 shall be given priority. Each of the Agency's periodic
2130	2130	10 updates to its long-term renewable resources
2131	2131	11 procurement plan to incorporate the procurement
2132	2132	12 described in this subparagraph (iv) shall also include
2133	2133	13 the proposed quantities or blocks, pricing, and
2134	2134	14 contract terms applicable to the procurement as
2135	2135	15 indicated herein. In each such update and procurement,
2136	2136	16 the Agency shall set the renewable energy credit price
2137	2137	17 and establish payment terms for the renewable energy
2138	2138	18 credits procured pursuant to this subparagraph (iv)
2139	2139	19 that make it feasible and affordable for public
2140	2140	20 schools to install photovoltaic distributed renewable
2141	2141	21 energy devices on their premises, including, but not
2142	2142	22 limited to, those public schools subject to the
2143	2143	23 prioritization provisions of this subparagraph. For
2144	2144	24 the purposes of this item (iv):
2145	2145	25 "Environmental Justice Community" shall have the
2146	2146	26 same meaning set forth in the Agency's long-term
2147	2147
2148	2148
2149	2149
2150	2150
2151	2151
2152	2152	SB1442 - 59 - LRB104 11424 BDA 21512 b
2153	2153
2154	2154
2155	2155	SB1442- 60 -LRB104 11424 BDA 21512 b SB1442 - 60 - LRB104 11424 BDA 21512 b
2156	2156	SB1442 - 60 - LRB104 11424 BDA 21512 b
2157	2157	1 renewable resources procurement plan;
2158	2158	2 "Organization Unit", "Tier 1" and "Tier 2" shall
2159	2159	3 have the meanings set for in Section 18-8.15 of the
2160	2160	4 School Code;
2161	2161	5 "Public schools" shall have the meaning set forth
2162	2162	6 in Section 1-3 of the School Code and includes public
2163	2163	7 institutions of higher education, as defined in the
2164	2164	8 Board of Higher Education Act.
2165	2165	9 (v) At least 5% from community-driven community
2166	2166	10 solar projects intended to provide more direct and
2167	2167	11 tangible connection and benefits to the communities
2168	2168	12 which they serve or in which they operate and,
2169	2169	13 additionally, to increase the variety of community
2170	2170	14 solar locations, models, and options in Illinois. As
2171	2171	15 part of its long-term renewable resources procurement
2172	2172	16 plan, the Agency shall develop selection criteria for
2173	2173	17 projects participating in this category. Nothing in
2174	2174	18 this Section shall preclude the Agency from creating a
2175	2175	19 selection process that maximizes community ownership
2176	2176	20 and community benefits in selecting projects to
2177	2177	21 receive renewable energy credits. Selection criteria
2178	2178	22 shall include:
2179	2179	23 (1) community ownership or community
2180	2180	24 wealth-building;
2181	2181	25 (2) additional direct and indirect community
2182	2182	26 benefit, beyond project participation as a
2183	2183
2184	2184
2185	2185
2186	2186
2187	2187
2188	2188	SB1442 - 60 - LRB104 11424 BDA 21512 b
2189	2189
2190	2190
2191	2191	SB1442- 61 -LRB104 11424 BDA 21512 b SB1442 - 61 - LRB104 11424 BDA 21512 b
2192	2192	SB1442 - 61 - LRB104 11424 BDA 21512 b
2193	2193	1 subscriber, including, but not limited to,
2194	2194	2 economic, environmental, social, cultural, and
2195	2195	3 physical benefits;
2196	2196	4 (3) meaningful involvement in project
2197	2197	5 organization and development by community members
2198	2198	6 or nonprofit organizations or public entities
2199	2199	7 located in or serving the community;
2200	2200	8 (4) engagement in project operations and
2201	2201	9 management by nonprofit organizations, public
2202	2202	10 entities, or community members; and
2203	2203	11 (5) whether a project is developed in response
2204	2204	12 to a site-specific RFP developed by community
2205	2205	13 members or a nonprofit organization or public
2206	2206	14 entity located in or serving the community.
2207	2207	15 Selection criteria may also prioritize projects
2208	2208	16 that:
2209	2209	17 (1) are developed in collaboration with or to
2210	2210	18 provide complementary opportunities for the Clean
2211	2211	19 Jobs Workforce Network Program, the Illinois
2212	2212	20 Climate Works Preapprenticeship Program, the
2213	2213	21 Returning Residents Clean Jobs Training Program,
2214	2214	22 the Clean Energy Contractor Incubator Program, or
2215	2215	23 the Clean Energy Primes Contractor Accelerator
2216	2216	24 Program;
2217	2217	25 (2) increase the diversity of locations of
2218	2218	26 community solar projects in Illinois, including by
2219	2219
2220	2220
2221	2221
2222	2222
2223	2223
2224	2224	SB1442 - 61 - LRB104 11424 BDA 21512 b
2225	2225
2226	2226
2227	2227	SB1442- 62 -LRB104 11424 BDA 21512 b SB1442 - 62 - LRB104 11424 BDA 21512 b
2228	2228	SB1442 - 62 - LRB104 11424 BDA 21512 b
2229	2229	1 locating in urban areas and population centers;
2230	2230	2 (3) are located in Equity Investment Eligible
2231	2231	3 Communities;
2232	2232	4 (4) are not greenfield projects;
2233	2233	5 (5) serve only local subscribers;
2234	2234	6 (6) have a nameplate capacity that does not
2235	2235	7 exceed 500 kW;
2236	2236	8 (7) are developed by an equity eligible
2237	2237	9 contractor; or
2238	2238	10 (8) otherwise meaningfully advance the goals
2239	2239	11 of providing more direct and tangible connection
2240	2240	12 and benefits to the communities which they serve
2241	2241	13 or in which they operate and increasing the
2242	2242	14 variety of community solar locations, models, and
2243	2243	15 options in Illinois.
2244	2244	16 For the purposes of this item (v):
2245	2245	17 "Community" means a social unit in which people
2246	2246	18 come together regularly to effect change; a social
2247	2247	19 unit in which participants are marked by a cooperative
2248	2248	20 spirit, a common purpose, or shared interests or
2249	2249	21 characteristics; or a space understood by its
2250	2250	22 residents to be delineated through geographic
2251	2251	23 boundaries or landmarks.
2252	2252	24 "Community benefit" means a range of services and
2253	2253	25 activities that provide affirmative, economic,
2254	2254	26 environmental, social, cultural, or physical value to
2255	2255
2256	2256
2257	2257
2258	2258
2259	2259
2260	2260	SB1442 - 62 - LRB104 11424 BDA 21512 b
2261	2261
2262	2262
2263	2263	SB1442- 63 -LRB104 11424 BDA 21512 b SB1442 - 63 - LRB104 11424 BDA 21512 b
2264	2264	SB1442 - 63 - LRB104 11424 BDA 21512 b
2265	2265	1 a community; or a mechanism that enables economic
2266	2266	2 development, high-quality employment, and education
2267	2267	3 opportunities for local workers and residents, or
2268	2268	4 formal monitoring and oversight structures such that
2269	2269	5 community members may ensure that those services and
2270	2270	6 activities respond to local knowledge and needs.
2271	2271	7 "Community ownership" means an arrangement in
2272	2272	8 which an electric generating facility is, or over time
2273	2273	9 will be, in significant part, owned collectively by
2274	2274	10 members of the community to which an electric
2275	2275	11 generating facility provides benefits; members of that
2276	2276	12 community participate in decisions regarding the
2277	2277	13 governance, operation, maintenance, and upgrades of
2278	2278	14 and to that facility; and members of that community
2279	2279	15 benefit from regular use of that facility.
2280	2280	16 Terms and guidance within these criteria that are
2281	2281	17 not defined in this item (v) shall be defined by the
2282	2282	18 Agency, with stakeholder input, during the development
2283	2283	19 of the Agency's long-term renewable resources
2284	2284	20 procurement plan. The Agency shall develop regular
2285	2285	21 opportunities for projects to submit applications for
2286	2286	22 projects under this category, and develop selection
2287	2287	23 criteria that gives preference to projects that better
2288	2288	24 meet individual criteria as well as projects that
2289	2289	25 address a higher number of criteria.
2290	2290	26 (vi) At least 10% from distributed renewable
2291	2291
2292	2292
2293	2293
2294	2294
2295	2295
2296	2296	SB1442 - 63 - LRB104 11424 BDA 21512 b
2297	2297
2298	2298
2299	2299	SB1442- 64 -LRB104 11424 BDA 21512 b SB1442 - 64 - LRB104 11424 BDA 21512 b
2300	2300	SB1442 - 64 - LRB104 11424 BDA 21512 b
2301	2301	1 energy generation devices, which includes distributed
2302	2302	2 renewable energy devices with a nameplate capacity
2303	2303	3 under 5,000 kilowatts or photovoltaic community
2304	2304	4 renewable generation projects, from applicants that
2305	2305	5 are equity eligible contractors. The Agency may create
2306	2306	6 subcategories within this category to account for the
2307	2307	7 differences between project size and type. The Agency
2308	2308	8 shall propose to increase the percentage in this item
2309	2309	9 (vi) over time to 40% based on factors, including, but
2310	2310	10 not limited to, the number of equity eligible
2311	2311	11 contractors and capacity used in this item (vi) in
2312	2312	12 previous delivery years.
2313	2313	13 The Agency shall propose a payment structure for
2314	2314	14 contracts executed pursuant to this paragraph under
2315	2315	15 which, upon a demonstration of qualification or need,
2316	2316	16 applicant firms are advanced capital disbursed after
2317	2317	17 contract execution but before the contracted project's
2318	2318	18 energization. The amount or percentage of capital
2319	2319	19 advanced prior to project energization shall be
2320	2320	20 sufficient to both cover any increase in development
2321	2321	21 costs resulting from prevailing wage requirements or
2322	2322	22 project-labor agreements, and designed to overcome
2323	2323	23 barriers in access to capital faced by equity eligible
2324	2324	24 contractors. The amount or percentage of advanced
2325	2325	25 capital may vary by subcategory within this category
2326	2326	26 and by an applicant's demonstration of need, with such
2327	2327
2328	2328
2329	2329
2330	2330
2331	2331
2332	2332	SB1442 - 64 - LRB104 11424 BDA 21512 b
2333	2333
2334	2334
2335	2335	SB1442- 65 -LRB104 11424 BDA 21512 b SB1442 - 65 - LRB104 11424 BDA 21512 b
2336	2336	SB1442 - 65 - LRB104 11424 BDA 21512 b
2337	2337	1 levels to be established through the Long-Term
2338	2338	2 Renewable Resources Procurement Plan authorized under
2339	2339	3 subparagraph (A) of paragraph (1) of subsection (c) of
2340	2340	4 this Section.
2341	2341	5 Contracts developed featuring capital advanced
2342	2342	6 prior to a project's energization shall feature
2343	2343	7 provisions to ensure both the successful development
2344	2344	8 of applicant projects and the delivery of the
2345	2345	9 renewable energy credits for the full term of the
2346	2346	10 contract, including ongoing collateral requirements
2347	2347	11 and other provisions deemed necessary by the Agency,
2348	2348	12 and may include energization timelines longer than for
2349	2349	13 comparable project types. The percentage or amount of
2350	2350	14 capital advanced prior to project energization shall
2351	2351	15 not operate to increase the overall contract value,
2352	2352	16 however contracts executed under this subparagraph may
2353	2353	17 feature renewable energy credit prices higher than
2354	2354	18 those offered to similar projects participating in
2355	2355	19 other categories. Capital advanced prior to
2356	2356	20 energization shall serve to reduce the ratable
2357	2357	21 payments made after energization under items (ii) and
2358	2358	22 (iii) of subparagraph (L) or payments made for each
2359	2359	23 renewable energy credit delivery under item (iv) of
2360	2360	24 subparagraph (L).
2361	2361	25 (vii) The remaining capacity shall be allocated by
2362	2362	26 the Agency in order to respond to market demand. The
2363	2363
2364	2364
2365	2365
2366	2366
2367	2367
2368	2368	SB1442 - 65 - LRB104 11424 BDA 21512 b
2369	2369
2370	2370
2371	2371	SB1442- 66 -LRB104 11424 BDA 21512 b SB1442 - 66 - LRB104 11424 BDA 21512 b
2372	2372	SB1442 - 66 - LRB104 11424 BDA 21512 b
2373	2373	1 Agency shall allocate any discretionary capacity prior
2374	2374	2 to the beginning of each delivery year.
2375	2375	3 To the extent there is uncontracted capacity from any
2376	2376	4 block in any of categories (i) through (vi) at the end of a
2377	2377	5 delivery year, the Agency shall redistribute that capacity
2378	2378	6 to one or more other categories giving priority to
2379	2379	7 categories with projects on a waitlist. The redistributed
2380	2380	8 capacity shall be added to the annual capacity in the
2381	2381	9 subsequent delivery year, and the price for renewable
2382	2382	10 energy credits shall be the price for the new delivery
2383	2383	11 year. Redistributed capacity shall not be considered
2384	2384	12 redistributed when determining whether the goals in this
2385	2385	13 subsection (K) have been met.
2386	2386	14 Notwithstanding anything to the contrary, as the
2387	2387	15 Agency increases the capacity in item (vi) to 40% over
2388	2388	16 time, the Agency may reduce the capacity of items (i)
2389	2389	17 through (v) proportionate to the capacity of the
2390	2390	18 categories of projects in item (vi), to achieve a balance
2391	2391	19 of project types.
2392	2392	20 The Adjustable Block program shall be designed to
2393	2393	21 ensure that renewable energy credits are procured from
2394	2394	22 projects in diverse locations and are not concentrated in
2395	2395	23 a few regional areas.
2396	2396	24 (L) Notwithstanding provisions for advancing capital
2397	2397	25 prior to project energization found in item (vi) of
2398	2398	26 subparagraph (K), the procurement of photovoltaic
2399	2399
2400	2400
2401	2401
2402	2402
2403	2403
2404	2404	SB1442 - 66 - LRB104 11424 BDA 21512 b
2405	2405
2406	2406
2407	2407	SB1442- 67 -LRB104 11424 BDA 21512 b SB1442 - 67 - LRB104 11424 BDA 21512 b
2408	2408	SB1442 - 67 - LRB104 11424 BDA 21512 b
2409	2409	1 renewable energy credits under items (i) through (vi) of
2410	2410	2 subparagraph (K) of this paragraph (1) shall otherwise be
2411	2411	3 subject to the following contract and payment terms:
2412	2412	4 (i) (Blank).
2413	2413	5 (ii) For those renewable energy credits that
2414	2414	6 qualify and are procured under item (i) of
2415	2415	7 subparagraph (K) of this paragraph (1), and any
2416	2416	8 similar category projects that are procured under item
2417	2417	9 (vi) of subparagraph (K) of this paragraph (1) that
2418	2418	10 qualify and are procured under item (vi), the contract
2419	2419	11 length shall be 15 years. The renewable energy credit
2420	2420	12 delivery contract value shall be paid in full, based
2421	2421	13 on the estimated generation during the first 15 years
2422	2422	14 of operation, by the contracting utilities at the time
2423	2423	15 that the facility producing the renewable energy
2424	2424	16 credits is interconnected at the distribution system
2425	2425	17 level of the utility and verified as energized and
2426	2426	18 compliant by the Program Administrator. The electric
2427	2427	19 utility shall receive and retire all renewable energy
2428	2428	20 credits generated by the project for the first 15
2429	2429	21 years of operation. Renewable energy credits generated
2430	2430	22 by the project thereafter shall not be transferred
2431	2431	23 under the renewable energy credit delivery contract
2432	2432	24 with the counterparty electric utility.
2433	2433	25 (iii) For those renewable energy credits that
2434	2434	26 qualify and are procured under item (ii) and (v) of
2435	2435
2436	2436
2437	2437
2438	2438
2439	2439
2440	2440	SB1442 - 67 - LRB104 11424 BDA 21512 b
2441	2441
2442	2442
2443	2443	SB1442- 68 -LRB104 11424 BDA 21512 b SB1442 - 68 - LRB104 11424 BDA 21512 b
2444	2444	SB1442 - 68 - LRB104 11424 BDA 21512 b
2445	2445	1 subparagraph (K) of this paragraph (1) and any like
2446	2446	2 projects similar category that qualify and are
2447	2447	3 procured under item (vi), the contract length shall be
2448	2448	4 15 years. 15% of the renewable energy credit delivery
2449	2449	5 contract value, based on the estimated generation
2450	2450	6 during the first 15 years of operation, shall be paid
2451	2451	7 by the contracting utilities at the time that the
2452	2452	8 facility producing the renewable energy credits is
2453	2453	9 interconnected at the distribution system level of the
2454	2454	10 utility and verified as energized and compliant by the
2455	2455	11 Program Administrator. The remaining portion shall be
2456	2456	12 paid ratably over the subsequent 6-year period. The
2457	2457	13 electric utility shall receive and retire all
2458	2458	14 renewable energy credits generated by the project for
2459	2459	15 the first 15 years of operation. Renewable energy
2460	2460	16 credits generated by the project thereafter shall not
2461	2461	17 be transferred under the renewable energy credit
2462	2462	18 delivery contract with the counterparty electric
2463	2463	19 utility.
2464	2464	20 (iv) For those renewable energy credits that
2465	2465	21 qualify and are procured under items (iii) and (iv) of
2466	2466	22 subparagraph (K) of this paragraph (1), and any like
2467	2467	23 projects that qualify and are procured under item
2468	2468	24 (vi), the renewable energy credit delivery contract
2469	2469	25 length shall be 20 years and shall be paid over the
2470	2470	26 delivery term, not to exceed during each delivery year
2471	2471
2472	2472
2473	2473
2474	2474
2475	2475
2476	2476	SB1442 - 68 - LRB104 11424 BDA 21512 b
2477	2477
2478	2478
2479	2479	SB1442- 69 -LRB104 11424 BDA 21512 b SB1442 - 69 - LRB104 11424 BDA 21512 b
2480	2480	SB1442 - 69 - LRB104 11424 BDA 21512 b
2481	2481	1 the contract price multiplied by the estimated annual
2482	2482	2 renewable energy credit generation amount. If
2483	2483	3 generation of renewable energy credits during a
2484	2484	4 delivery year exceeds the estimated annual generation
2485	2485	5 amount, the excess renewable energy credits shall be
2486	2486	6 carried forward to future delivery years and shall not
2487	2487	7 expire during the delivery term. If generation of
2488	2488	8 renewable energy credits during a delivery year,
2489	2489	9 including carried forward excess renewable energy
2490	2490	10 credits, if any, is less than the estimated annual
2491	2491	11 generation amount, payments during such delivery year
2492	2492	12 will not exceed the quantity generated plus the
2493	2493	13 quantity carried forward multiplied by the contract
2494	2494	14 price. The electric utility shall receive all
2495	2495	15 renewable energy credits generated by the project
2496	2496	16 during the first 20 years of operation and retire all
2497	2497	17 renewable energy credits paid for under this item (iv)
2498	2498	18 and return at the end of the delivery term all
2499	2499	19 renewable energy credits that were not paid for.
2500	2500	20 Renewable energy credits generated by the project
2501	2501	21 thereafter shall not be transferred under the
2502	2502	22 renewable energy credit delivery contract with the
2503	2503	23 counterparty electric utility. Notwithstanding the
2504	2504	24 preceding, for those projects participating under item
2505	2505	25 (iii) of subparagraph (K), the contract price for a
2506	2506	26 delivery year shall be based on subscription levels as
2507	2507
2508	2508
2509	2509
2510	2510
2511	2511
2512	2512	SB1442 - 69 - LRB104 11424 BDA 21512 b
2513	2513
2514	2514
2515	2515	SB1442- 70 -LRB104 11424 BDA 21512 b SB1442 - 70 - LRB104 11424 BDA 21512 b
2516	2516	SB1442 - 70 - LRB104 11424 BDA 21512 b
2517	2517	1 measured on the higher of the first business day of the
2518	2518	2 delivery year or the first business day 6 months after
2519	2519	3 the first business day of the delivery year.
2520	2520	4 Subscription of 90% of nameplate capacity or greater
2521	2521	5 shall be deemed to be fully subscribed for the
2522	2522	6 purposes of this item (iv). For projects receiving a
2523	2523	7 20-year delivery contract, REC prices shall be
2524	2524	8 adjusted downward for consistency with the incentive
2525	2525	9 levels previously determined to be necessary to
2526	2526	10 support projects under 15-year delivery contracts,
2527	2527	11 taking into consideration any additional new
2528	2528	12 requirements placed on the projects, including, but
2529	2529	13 not limited to, labor standards.
2530	2530	14 (v) Each contract shall include provisions to
2531	2531	15 ensure the delivery of the estimated quantity of
2532	2532	16 renewable energy credits and ongoing collateral
2533	2533	17 requirements and other provisions deemed appropriate
2534	2534	18 by the Agency.
2535	2535	19 (vi) The utility shall be the counterparty to the
2536	2536	20 contracts executed under this subparagraph (L) that
2537	2537	21 are approved by the Commission under the process
2538	2538	22 described in Section 16-111.5 of the Public Utilities
2539	2539	23 Act. No contract shall be executed for an amount that
2540	2540	24 is less than one renewable energy credit per year.
2541	2541	25 (vii) If, at any time, approved applications for
2542	2542	26 the Adjustable Block program exceed funds collected by
2543	2543
2544	2544
2545	2545
2546	2546
2547	2547
2548	2548	SB1442 - 70 - LRB104 11424 BDA 21512 b
2549	2549
2550	2550
2551	2551	SB1442- 71 -LRB104 11424 BDA 21512 b SB1442 - 71 - LRB104 11424 BDA 21512 b
2552	2552	SB1442 - 71 - LRB104 11424 BDA 21512 b
2553	2553	1 the electric utility or would cause the Agency to
2554	2554	2 exceed the limitation described in subparagraph (E) of
2555	2555	3 this paragraph (1) on the amount of renewable energy
2556	2556	4 resources that may be procured, then the Agency may
2557	2557	5 consider future uncommitted funds to be reserved for
2558	2558	6 these contracts on a first-come, first-served basis.
2559	2559	7 (viii) Nothing in this Section shall require the
2560	2560	8 utility to advance any payment or pay any amounts that
2561	2561	9 exceed the actual amount of revenues anticipated to be
2562	2562	10 collected by the utility under paragraph (6) of this
2563	2563	11 subsection (c) and subsection (k) of Section 16-108 of
2564	2564	12 the Public Utilities Act inclusive of eligible funds
2565	2565	13 collected in prior years and alternative compliance
2566	2566	14 payments for use by the utility, and contracts
2567	2567	15 executed under this Section shall expressly
2568	2568	16 incorporate this limitation.
2569	2569	17 (ix) Notwithstanding other requirements of this
2570	2570	18 subparagraph (L), no modification shall be required to
2571	2571	19 Adjustable Block program contracts if they were
2572	2572	20 already executed prior to the establishment, approval,
2573	2573	21 and implementation of new contract forms as a result
2574	2574	22 of this amendatory Act of the 102nd General Assembly.
2575	2575	23 (x) Contracts may be assignable, but only to
2576	2576	24 entities first deemed by the Agency to have met
2577	2577	25 program terms and requirements applicable to direct
2578	2578	26 program participation. In developing contracts for the
2579	2579
2580	2580
2581	2581
2582	2582
2583	2583
2584	2584	SB1442 - 71 - LRB104 11424 BDA 21512 b
2585	2585
2586	2586
2587	2587	SB1442- 72 -LRB104 11424 BDA 21512 b SB1442 - 72 - LRB104 11424 BDA 21512 b
2588	2588	SB1442 - 72 - LRB104 11424 BDA 21512 b
2589	2589	1 delivery of renewable energy credits, the Agency shall
2590	2590	2 be permitted to establish fees applicable to each
2591	2591	3 contract assignment.
2592	2592	4 (M) The Agency shall be authorized to retain one or
2593	2593	5 more experts or expert consulting firms to develop,
2594	2594	6 administer, implement, operate, and evaluate the
2595	2595	7 Adjustable Block program described in subparagraph (K) of
2596	2596	8 this paragraph (1), and the Agency shall retain the
2597	2597	9 consultant or consultants in the same manner, to the
2598	2598	10 extent practicable, as the Agency retains others to
2599	2599	11 administer provisions of this Act, including, but not
2600	2600	12 limited to, the procurement administrator. The selection
2601	2601	13 of experts and expert consulting firms and the procurement
2602	2602	14 process described in this subparagraph (M) are exempt from
2603	2603	15 the requirements of Section 20-10 of the Illinois
2604	2604	16 Procurement Code, under Section 20-10 of that Code. The
2605	2605	17 Agency shall strive to minimize administrative expenses in
2606	2606	18 the implementation of the Adjustable Block program.
2607	2607	19 The Program Administrator may charge application fees
2608	2608	20 to participating firms to cover the cost of program
2609	2609	21 administration. Any application fee amounts shall
2610	2610	22 initially be determined through the long-term renewable
2611	2611	23 resources procurement plan, and modifications to any
2612	2612	24 application fee that deviate more than 25% from the
2613	2613	25 Commission's approved value must be approved by the
2614	2614	26 Commission as a long-term plan revision under Section
2615	2615
2616	2616
2617	2617
2618	2618
2619	2619
2620	2620	SB1442 - 72 - LRB104 11424 BDA 21512 b
2621	2621
2622	2622
2623	2623	SB1442- 73 -LRB104 11424 BDA 21512 b SB1442 - 73 - LRB104 11424 BDA 21512 b
2624	2624	SB1442 - 73 - LRB104 11424 BDA 21512 b
2625	2625	1 16-111.5 of the Public Utilities Act. The Agency shall
2626	2626	2 consider stakeholder feedback when making adjustments to
2627	2627	3 application fees and shall notify stakeholders in advance
2628	2628	4 of any planned changes.
2629	2629	5 In addition to covering the costs of program
2630	2630	6 administration, the Agency, in conjunction with its
2631	2631	7 Program Administrator, may also use the proceeds of such
2632	2632	8 fees charged to participating firms to support public
2633	2633	9 education and ongoing regional and national coordination
2634	2634	10 with nonprofit organizations, public bodies, and others
2635	2635	11 engaged in the implementation of renewable energy
2636	2636	12 incentive programs or similar initiatives. This work may
2637	2637	13 include developing papers and reports, hosting regional
2638	2638	14 and national conferences, and other work deemed necessary
2639	2639	15 by the Agency to position the State of Illinois as a
2640	2640	16 national leader in renewable energy incentive program
2641	2641	17 development and administration.
2642	2642	18 The Agency and its consultant or consultants shall
2643	2643	19 monitor block activity, share program activity with
2644	2644	20 stakeholders and conduct quarterly meetings to discuss
2645	2645	21 program activity and market conditions. If necessary, the
2646	2646	22 Agency may make prospective administrative adjustments to
2647	2647	23 the Adjustable Block program design, such as making
2648	2648	24 adjustments to purchase prices as necessary to achieve the
2649	2649	25 goals of this subsection (c). Program modifications to any
2650	2650	26 block price that do not deviate from the Commission's
2651	2651
2652	2652
2653	2653
2654	2654
2655	2655
2656	2656	SB1442 - 73 - LRB104 11424 BDA 21512 b
2657	2657
2658	2658
2659	2659	SB1442- 74 -LRB104 11424 BDA 21512 b SB1442 - 74 - LRB104 11424 BDA 21512 b
2660	2660	SB1442 - 74 - LRB104 11424 BDA 21512 b
2661	2661	1 approved value by more than 10% shall take effect
2662	2662	2 immediately and are not subject to Commission review and
2663	2663	3 approval. Program modifications to any block price that
2664	2664	4 deviate more than 10% from the Commission's approved value
2665	2665	5 must be approved by the Commission as a long-term plan
2666	2666	6 amendment under Section 16-111.5 of the Public Utilities
2667	2667	7 Act. The Agency shall consider stakeholder feedback when
2668	2668	8 making adjustments to the Adjustable Block design and
2669	2669	9 shall notify stakeholders in advance of any planned
2670	2670	10 changes.
2671	2671	11 The Agency and its program administrators for both the
2672	2672	12 Adjustable Block program and the Illinois Solar for All
2673	2673	13 Program, consistent with the requirements of this
2674	2674	14 subsection (c) and subsection (b) of Section 1-56 of this
2675	2675	15 Act, shall propose the Adjustable Block program terms,
2676	2676	16 conditions, and requirements, including the prices to be
2677	2677	17 paid for renewable energy credits, where applicable, and
2678	2678	18 requirements applicable to participating entities and
2679	2679	19 project applications, through the development, review, and
2680	2680	20 approval of the Agency's long-term renewable resources
2681	2681	21 procurement plan described in this subsection (c) and
2682	2682	22 paragraph (5) of subsection (b) of Section 16-111.5 of the
2683	2683	23 Public Utilities Act. Terms, conditions, and requirements
2684	2684	24 for program participation shall include the following:
2685	2685	25 (i) The Agency shall establish a registration
2686	2686	26 process for entities seeking to qualify for
2687	2687
2688	2688
2689	2689
2690	2690
2691	2691
2692	2692	SB1442 - 74 - LRB104 11424 BDA 21512 b
2693	2693
2694	2694
2695	2695	SB1442- 75 -LRB104 11424 BDA 21512 b SB1442 - 75 - LRB104 11424 BDA 21512 b
2696	2696	SB1442 - 75 - LRB104 11424 BDA 21512 b
2697	2697	1 program-administered incentive funding and establish
2698	2698	2 baseline qualifications for vendor approval. The
2699	2699	3 Agency must maintain a list of approved entities on
2700	2700	4 each program's website, and may revoke a vendor's
2701	2701	5 ability to receive program-administered incentive
2702	2702	6 funding status upon a determination that the vendor
2703	2703	7 failed to comply with contract terms, the law, or
2704	2704	8 other program requirements.
2705	2705	9 (ii) The Agency shall establish program
2706	2706	10 requirements and minimum contract terms to ensure
2707	2707	11 projects are properly installed and produce their
2708	2708	12 expected amounts of energy. Program requirements may
2709	2709	13 include on-site inspections and photo documentation of
2710	2710	14 projects under construction. The Agency may require
2711	2711	15 repairs, alterations, or additions to remedy any
2712	2712	16 material deficiencies discovered. Vendors who have a
2713	2713	17 disproportionately high number of deficient systems
2714	2714	18 may lose their eligibility to continue to receive
2715	2715	19 State-administered incentive funding through Agency
2716	2716	20 programs and procurements.
2717	2717	21 (iii) To discourage deceptive marketing or other
2718	2718	22 bad faith business practices, the Agency may require
2719	2719	23 direct program participants, including agents
2720	2720	24 operating on their behalf, to provide standardized
2721	2721	25 disclosures to a customer prior to that customer's
2722	2722	26 execution of a contract for the development of a
2723	2723
2724	2724
2725	2725
2726	2726
2727	2727
2728	2728	SB1442 - 75 - LRB104 11424 BDA 21512 b
2729	2729
2730	2730
2731	2731	SB1442- 76 -LRB104 11424 BDA 21512 b SB1442 - 76 - LRB104 11424 BDA 21512 b
2732	2732	SB1442 - 76 - LRB104 11424 BDA 21512 b
2733	2733	1 distributed generation system or a subscription to a
2734	2734	2 community solar project.
2735	2735	3 (iv) The Agency shall establish one or multiple
2736	2736	4 Consumer Complaints Centers to accept complaints
2737	2737	5 regarding businesses that participate in, or otherwise
2738	2738	6 benefit from, State-administered incentive funding
2739	2739	7 through Agency-administered programs. The Agency shall
2740	2740	8 maintain a public database of complaints with any
2741	2741	9 confidential or particularly sensitive information
2742	2742	10 redacted from public entries.
2743	2743	11 (v) Through a filing in the proceeding for the
2744	2744	12 approval of its long-term renewable energy resources
2745	2745	13 procurement plan, the Agency shall provide an annual
2746	2746	14 written report to the Illinois Commerce Commission
2747	2747	15 documenting the frequency and nature of complaints and
2748	2748	16 any enforcement actions taken in response to those
2749	2749	17 complaints.
2750	2750	18 (vi) The Agency shall schedule regular meetings
2751	2751	19 with representatives of the Office of the Attorney
2752	2752	20 General, the Illinois Commerce Commission, consumer
2753	2753	21 protection groups, and other interested stakeholders
2754	2754	22 to share relevant information about consumer
2755	2755	23 protection, project compliance, and complaints
2756	2756	24 received.
2757	2757	25 (vii) To the extent that complaints received
2758	2758	26 implicate the jurisdiction of the Office of the
2759	2759
2760	2760
2761	2761
2762	2762
2763	2763
2764	2764	SB1442 - 76 - LRB104 11424 BDA 21512 b
2765	2765
2766	2766
2767	2767	SB1442- 77 -LRB104 11424 BDA 21512 b SB1442 - 77 - LRB104 11424 BDA 21512 b
2768	2768	SB1442 - 77 - LRB104 11424 BDA 21512 b
2769	2769	1 Attorney General, the Illinois Commerce Commission, or
2770	2770	2 local, State, or federal law enforcement, the Agency
2771	2771	3 shall also refer complaints to those entities as
2772	2772	4 appropriate.
2773	2773	5 (N) The Agency shall establish the terms, conditions,
2774	2774	6 and program requirements for photovoltaic community
2775	2775	7 renewable generation projects with a goal to expand access
2776	2776	8 to a broader group of energy consumers, to ensure robust
2777	2777	9 participation opportunities for residential and small
2778	2778	10 commercial customers and those who cannot install
2779	2779	11 renewable energy on their own properties. Subject to
2780	2780	12 reasonable limitations, any plan approved by the
2781	2781	13 Commission shall allow subscriptions to community
2782	2782	14 renewable generation projects to be portable and
2783	2783	15 transferable. For purposes of this subparagraph (N),
2784	2784	16 "portable" means that subscriptions may be retained by the
2785	2785	17 subscriber even if the subscriber relocates or changes its
2786	2786	18 address within the same utility service territory; and
2787	2787	19 "transferable" means that a subscriber may assign or sell
2788	2788	20 subscriptions to another person within the same utility
2789	2789	21 service territory.
2790	2790	22 Through the development of its long-term renewable
2791	2791	23 resources procurement plan, the Agency may consider
2792	2792	24 whether community renewable generation projects utilizing
2793	2793	25 technologies other than photovoltaics should be supported
2794	2794	26 through State-administered incentive funding, and may
2795	2795
2796	2796
2797	2797
2798	2798
2799	2799
2800	2800	SB1442 - 77 - LRB104 11424 BDA 21512 b
2801	2801
2802	2802
2803	2803	SB1442- 78 -LRB104 11424 BDA 21512 b SB1442 - 78 - LRB104 11424 BDA 21512 b
2804	2804	SB1442 - 78 - LRB104 11424 BDA 21512 b
2805	2805	1 issue requests for information to gauge market demand.
2806	2806	2 Electric utilities shall provide a monetary credit to
2807	2807	3 a subscriber's subsequent bill for service for the
2808	2808	4 proportional output of a community renewable generation
2809	2809	5 project attributable to that subscriber as specified in
2810	2810	6 Section 16-107.5 of the Public Utilities Act.
2811	2811	7 The Agency shall purchase renewable energy credits
2812	2812	8 from subscribed shares of photovoltaic community renewable
2813	2813	9 generation projects through the Adjustable Block program
2814	2814	10 described in subparagraph (K) of this paragraph (1) or
2815	2815	11 through the Illinois Solar for All Program described in
2816	2816	12 Section 1-56 of this Act. The electric utility shall
2817	2817	13 purchase any unsubscribed energy from community renewable
2818	2818	14 generation projects that are Qualifying Facilities ("QF")
2819	2819	15 under the electric utility's tariff for purchasing the
2820	2820	16 output from QFs under Public Utilities Regulatory Policies
2821	2821	17 Act of 1978.
2822	2822	18 The owners of and any subscribers to a community
2823	2823	19 renewable generation project shall not be considered
2824	2824	20 public utilities or alternative retail electricity
2825	2825	21 suppliers under the Public Utilities Act solely as a
2826	2826	22 result of their interest in or subscription to a community
2827	2827	23 renewable generation project and shall not be required to
2828	2828	24 become an alternative retail electric supplier by
2829	2829	25 participating in a community renewable generation project
2830	2830	26 with a public utility.
2831	2831
2832	2832
2833	2833
2834	2834
2835	2835
2836	2836	SB1442 - 78 - LRB104 11424 BDA 21512 b
2837	2837
2838	2838
2839	2839	SB1442- 79 -LRB104 11424 BDA 21512 b SB1442 - 79 - LRB104 11424 BDA 21512 b
2840	2840	SB1442 - 79 - LRB104 11424 BDA 21512 b
2841	2841	1 (O) For the delivery year beginning June 1, 2018, the
2842	2842	2 long-term renewable resources procurement plan required by
2843	2843	3 this subsection (c) shall provide for the Agency to
2844	2844	4 procure contracts to continue offering the Illinois Solar
2845	2845	5 for All Program described in subsection (b) of Section
2846	2846	6 1-56 of this Act, and the contracts approved by the
2847	2847	7 Commission shall be executed by the utilities that are
2848	2848	8 subject to this subsection (c). The long-term renewable
2849	2849	9 resources procurement plan shall allocate up to
2850	2850	10 $50,000,000 per delivery year to fund the programs, and
2851	2851	11 the plan shall determine the amount of funding to be
2852	2852	12 apportioned to the programs identified in subsection (b)
2853	2853	13 of Section 1-56 of this Act; provided that for the
2854	2854	14 delivery years beginning June 1, 2021, June 1, 2022, and
2855	2855	15 June 1, 2023, the long-term renewable resources
2856	2856	16 procurement plan may average the annual budgets over a
2857	2857	17 3-year period to account for program ramp-up. For the
2858	2858	18 delivery years beginning June 1, 2021, June 1, 2024, June
2859	2859	19 1, 2027, and June 1, 2030 and additional $10,000,000 shall
2860	2860	20 be provided to the Department of Commerce and Economic
2861	2861	21 Opportunity to implement the workforce development
2862	2862	22 programs and reporting as outlined in Section 16-108.12 of
2863	2863	23 the Public Utilities Act. In making the determinations
2864	2864	24 required under this subparagraph (O), the Commission shall
2865	2865	25 consider the experience and performance under the programs
2866	2866	26 and any evaluation reports. The Commission shall also
2867	2867
2868	2868
2869	2869
2870	2870
2871	2871
2872	2872	SB1442 - 79 - LRB104 11424 BDA 21512 b
2873	2873
2874	2874
2875	2875	SB1442- 80 -LRB104 11424 BDA 21512 b SB1442 - 80 - LRB104 11424 BDA 21512 b
2876	2876	SB1442 - 80 - LRB104 11424 BDA 21512 b
2877	2877	1 provide for an independent evaluation of those programs on
2878	2878	2 a periodic basis that are funded under this subparagraph
2879	2879	3 (O).
2880	2880	4 (P) All programs and procurements under this
2881	2881	5 subsection (c) shall be designed to encourage
2882	2882	6 participating projects to use a diverse and equitable
2883	2883	7 workforce and a diverse set of contractors, including
2884	2884	8 minority-owned businesses, disadvantaged businesses,
2885	2885	9 trade unions, graduates of any workforce training programs
2886	2886	10 administered under this Act, and small businesses.
2887	2887	11 The Agency shall develop a method to optimize
2888	2888	12 procurement of renewable energy credits from proposed
2889	2889	13 utility-scale projects that are located in communities
2890	2890	14 eligible to receive Energy Transition Community Grants
2891	2891	15 pursuant to Section 10-20 of the Energy Community
2892	2892	16 Reinvestment Act. If this requirement conflicts with other
2893	2893	17 provisions of law or the Agency determines that full
2894	2894	18 compliance with the requirements of this subparagraph (P)
2895	2895	19 would be unreasonably costly or administratively
2896	2896	20 impractical, the Agency is to propose alternative
2897	2897	21 approaches to achieve development of renewable energy
2898	2898	22 resources in communities eligible to receive Energy
2899	2899	23 Transition Community Grants pursuant to Section 10-20 of
2900	2900	24 the Energy Community Reinvestment Act or seek an exemption
2901	2901	25 from this requirement from the Commission.
2902	2902	26 (Q) Each facility listed in subitems (i) through (ix)
2903	2903
2904	2904
2905	2905
2906	2906
2907	2907
2908	2908	SB1442 - 80 - LRB104 11424 BDA 21512 b
2909	2909
2910	2910
2911	2911	SB1442- 81 -LRB104 11424 BDA 21512 b SB1442 - 81 - LRB104 11424 BDA 21512 b
2912	2912	SB1442 - 81 - LRB104 11424 BDA 21512 b
2913	2913	1 of item (1) of this subparagraph (Q) for which a renewable
2914	2914	2 energy credit delivery contract is signed after the
2915	2915	3 effective date of this amendatory Act of the 102nd General
2916	2916	4 Assembly is subject to the following requirements through
2917	2917	5 the Agency's long-term renewable resources procurement
2918	2918	6 plan:
2919	2919	7 (1) Each facility shall be subject to the
2920	2920	8 prevailing wage requirements included in the
2921	2921	9 Prevailing Wage Act. The Agency shall require
2922	2922	10 verification that all construction performed on the
2923	2923	11 facility by the renewable energy credit delivery
2924	2924	12 contract holder, its contractors, or its
2925	2925	13 subcontractors relating to construction of the
2926	2926	14 facility is performed by construction employees
2927	2927	15 receiving an amount for that work equal to or greater
2928	2928	16 than the general prevailing rate, as that term is
2929	2929	17 defined in Section 3 of the Prevailing Wage Act. For
2930	2930	18 purposes of this item (1), "house of worship" means
2931	2931	19 property that is both (1) used exclusively by a
2932	2932	20 religious society or body of persons as a place for
2933	2933	21 religious exercise or religious worship and (2)
2934	2934	22 recognized as exempt from taxation pursuant to Section
2935	2935	23 15-40 of the Property Tax Code. This item (1) shall
2936	2936	24 apply to any the following:
2937	2937	25 (i) all new utility-scale wind projects;
2938	2938	26 (ii) all new utility-scale photovoltaic
2939	2939
2940	2940
2941	2941
2942	2942
2943	2943
2944	2944	SB1442 - 81 - LRB104 11424 BDA 21512 b
2945	2945
2946	2946
2947	2947	SB1442- 82 -LRB104 11424 BDA 21512 b SB1442 - 82 - LRB104 11424 BDA 21512 b
2948	2948	SB1442 - 82 - LRB104 11424 BDA 21512 b
2949	2949	1 projects;
2950	2950	2 (iii) all new brownfield photovoltaic
2951	2951	3 projects;
2952	2952	4 (iv) all new photovoltaic community renewable
2953	2953	5 energy facilities that qualify for item (iii) of
2954	2954	6 subparagraph (K) of this paragraph (1);
2955	2955	7 (v) all new community driven community
2956	2956	8 photovoltaic projects that qualify for item (v) of
2957	2957	9 subparagraph (K) of this paragraph (1);
2958	2958	10 (vi) all new photovoltaic projects on public
2959	2959	11 school land that qualify for item (iv) of
2960	2960	12 subparagraph (K) of this paragraph (1);
2961	2961	13 (vii) all new photovoltaic distributed
2962	2962	14 renewable energy generation devices that (1)
2963	2963	15 qualify for item (i) of subparagraph (K) of this
2964	2964	16 paragraph (1); (2) are not projects that serve
2965	2965	17 single-family or multi-family residential
2966	2966	18 buildings; and (3) are not houses of worship where
2967	2967	19 the aggregate capacity including collocated
2968	2968	20 projects would not exceed 100 kilowatts;
2969	2969	21 (viii) all new photovoltaic distributed
2970	2970	22 renewable energy generation devices that (1)
2971	2971	23 qualify for item (ii) of subparagraph (K) of this
2972	2972	24 paragraph (1); (2) are not projects that serve
2973	2973	25 single-family or multi-family residential
2974	2974	26 buildings; and (3) are not houses of worship where
2975	2975
2976	2976
2977	2977
2978	2978
2979	2979
2980	2980	SB1442 - 82 - LRB104 11424 BDA 21512 b
2981	2981
2982	2982
2983	2983	SB1442- 83 -LRB104 11424 BDA 21512 b SB1442 - 83 - LRB104 11424 BDA 21512 b
2984	2984	SB1442 - 83 - LRB104 11424 BDA 21512 b
2985	2985	1 the aggregate capacity including collocated
2986	2986	2 projects would not exceed 100 kilowatts;
2987	2987	3 (ix) all new, modernized, or retooled
2988	2988	4 hydropower facilities.
2989	2989	5 (2) Renewable energy credits procured from new
2990	2990	6 utility-scale wind projects, new utility-scale solar
2991	2991	7 projects, and new brownfield solar projects pursuant
2992	2992	8 to Agency procurement events occurring after the
2993	2993	9 effective date of this amendatory Act of the 102nd
2994	2994	10 General Assembly must be from facilities built by
2995	2995	11 general contractors that must enter into a project
2996	2996	12 labor agreement, as defined by this Act, prior to
2997	2997	13 construction. The project labor agreement shall be
2998	2998	14 filed with the Director in accordance with procedures
2999	2999	15 established by the Agency through its long-term
3000	3000	16 renewable resources procurement plan. Any information
3001	3001	17 submitted to the Agency in this item (2) shall be
3002	3002	18 considered commercially sensitive information. At a
3003	3003	19 minimum, the project labor agreement must provide the
3004	3004	20 names, addresses, and occupations of the owner of the
3005	3005	21 plant and the individuals representing the labor
3006	3006	22 organization employees participating in the project
3007	3007	23 labor agreement consistent with the Project Labor
3008	3008	24 Agreements Act. The agreement must also specify the
3009	3009	25 terms and conditions as defined by this Act.
3010	3010	26 (3) It is the intent of this Section to ensure that
3011	3011
3012	3012
3013	3013
3014	3014
3015	3015
3016	3016	SB1442 - 83 - LRB104 11424 BDA 21512 b
3017	3017
3018	3018
3019	3019	SB1442- 84 -LRB104 11424 BDA 21512 b SB1442 - 84 - LRB104 11424 BDA 21512 b
3020	3020	SB1442 - 84 - LRB104 11424 BDA 21512 b
3021	3021	1 economic development occurs across Illinois
3022	3022	2 communities, that emerging businesses may grow, and
3023	3023	3 that there is improved access to the clean energy
3024	3024	4 economy by persons who have greater economic burdens
3025	3025	5 to success. The Agency shall take into consideration
3026	3026	6 the unique cost of compliance of this subparagraph (Q)
3027	3027	7 that might be borne by equity eligible contractors,
3028	3028	8 shall include such costs when determining the price of
3029	3029	9 renewable energy credits in the Adjustable Block
3030	3030	10 program, and shall take such costs into consideration
3031	3031	11 in a nondiscriminatory manner when comparing bids for
3032	3032	12 competitive procurements. The Agency shall consider
3033	3033	13 costs associated with compliance whether in the
3034	3034	14 development, financing, or construction of projects.
3035	3035	15 The Agency shall periodically review the assumptions
3036	3036	16 in these costs and may adjust prices, in compliance
3037	3037	17 with subparagraph (M) of this paragraph (1).
3038	3038	18 (R) In its long-term renewable resources procurement
3039	3039	19 plan, the Agency shall establish a self-direct renewable
3040	3040	20 portfolio standard compliance program for eligible
3041	3041	21 self-direct customers that purchase renewable energy
3042	3042	22 credits from utility-scale wind and solar projects through
3043	3043	23 long-term agreements for purchase of renewable energy
3044	3044	24 credits as described in this Section. Such long-term
3045	3045	25 agreements may include the purchase of energy or other
3046	3046	26 products on a physical or financial basis and may involve
3047	3047
3048	3048
3049	3049
3050	3050
3051	3051
3052	3052	SB1442 - 84 - LRB104 11424 BDA 21512 b
3053	3053
3054	3054
3055	3055	SB1442- 85 -LRB104 11424 BDA 21512 b SB1442 - 85 - LRB104 11424 BDA 21512 b
3056	3056	SB1442 - 85 - LRB104 11424 BDA 21512 b
3057	3057	1 an alternative retail electric supplier as defined in
3058	3058	2 Section 16-102 of the Public Utilities Act. This program
3059	3059	3 shall take effect in the delivery year commencing June 1,
3060	3060	4 2023.
3061	3061	5 (1) For the purposes of this subparagraph:
3062	3062	6 "Eligible self-direct customer" means any retail
3063	3063	7 customers of an electric utility that serves 3,000,000
3064	3064	8 or more retail customers in the State and whose total
3065	3065	9 highest 30-minute demand was more than 10,000
3066	3066	10 kilowatts, or any retail customers of an electric
3067	3067	11 utility that serves less than 3,000,000 retail
3068	3068	12 customers but more than 500,000 retail customers in
3069	3069	13 the State and whose total highest 15-minute demand was
3070	3070	14 more than 10,000 kilowatts.
3071	3071	15 "Retail customer" has the meaning set forth in
3072	3072	16 Section 16-102 of the Public Utilities Act and
3073	3073	17 multiple retail customer accounts under the same
3074	3074	18 corporate parent may aggregate their account demands
3075	3075	19 to meet the 10,000 kilowatt threshold. The criteria
3076	3076	20 for determining whether this subparagraph is
3077	3077	21 applicable to a retail customer shall be based on the
3078	3078	22 12 consecutive billing periods prior to the start of
3079	3079	23 the year in which the application is filed.
3080	3080	24 (2) For renewable energy credits to count toward
3081	3081	25 the self-direct renewable portfolio standard
3082	3082	26 compliance program, they must:
3083	3083
3084	3084
3085	3085
3086	3086
3087	3087
3088	3088	SB1442 - 85 - LRB104 11424 BDA 21512 b
3089	3089
3090	3090
3091	3091	SB1442- 86 -LRB104 11424 BDA 21512 b SB1442 - 86 - LRB104 11424 BDA 21512 b
3092	3092	SB1442 - 86 - LRB104 11424 BDA 21512 b
3093	3093	1 (i) qualify as renewable energy credits as
3094	3094	2 defined in Section 1-10 of this Act;
3095	3095	3 (ii) be sourced from one or more renewable
3096	3096	4 energy generating facilities that comply with the
3097	3097	5 geographic requirements as set forth in
3098	3098	6 subparagraph (I) of paragraph (1) of subsection
3099	3099	7 (c) as interpreted through the Agency's long-term
3100	3100	8 renewable resources procurement plan, or, where
3101	3101	9 applicable, the geographic requirements that
3102	3102	10 governed utility-scale renewable energy credits at
3103	3103	11 the time the eligible self-direct customer entered
3104	3104	12 into the applicable renewable energy credit
3105	3105	13 purchase agreement;
3106	3106	14 (iii) be procured through long-term contracts
3107	3107	15 with term lengths of at least 10 years either
3108	3108	16 directly with the renewable energy generating
3109	3109	17 facility or through a bundled power purchase
3110	3110	18 agreement, a virtual power purchase agreement, an
3111	3111	19 agreement between the renewable generating
3112	3112	20 facility, an alternative retail electric supplier,
3113	3113	21 and the customer, or such other structure as is
3114	3114	22 permissible under this subparagraph (R);
3115	3115	23 (iv) be equivalent in volume to at least 40%
3116	3116	24 of the eligible self-direct customer's usage,
3117	3117	25 determined annually by the eligible self-direct
3118	3118	26 customer's usage during the previous delivery
3119	3119
3120	3120
3121	3121
3122	3122
3123	3123
3124	3124	SB1442 - 86 - LRB104 11424 BDA 21512 b
3125	3125
3126	3126
3127	3127	SB1442- 87 -LRB104 11424 BDA 21512 b SB1442 - 87 - LRB104 11424 BDA 21512 b
3128	3128	SB1442 - 87 - LRB104 11424 BDA 21512 b
3129	3129	1 year, measured to the nearest megawatt-hour;
3130	3130	2 (v) be retired by or on behalf of the large
3131	3131	3 energy customer;
3132	3132	4 (vi) be sourced from new utility-scale wind
3133	3133	5 projects or new utility-scale solar projects; and
3134	3134	6 (vii) if the contracts for renewable energy
3135	3135	7 credits are entered into after the effective date
3136	3136	8 of this amendatory Act of the 102nd General
3137	3137	9 Assembly, the new utility-scale wind projects or
3138	3138	10 new utility-scale solar projects must comply with
3139	3139	11 the requirements established in subparagraphs (P)
3140	3140	12 and (Q) of paragraph (1) of this subsection (c)
3141	3141	13 and subsection (c-10).
3142	3142	14 (3) The self-direct renewable portfolio standard
3143	3143	15 compliance program shall be designed to allow eligible
3144	3144	16 self-direct customers to procure new renewable energy
3145	3145	17 credits from new utility-scale wind projects or new
3146	3146	18 utility-scale photovoltaic projects. The Agency shall
3147	3147	19 annually determine the amount of utility-scale
3148	3148	20 renewable energy credits it will include each year
3149	3149	21 from the self-direct renewable portfolio standard
3150	3150	22 compliance program, subject to receiving qualifying
3151	3151	23 applications. In making this determination, the Agency
3152	3152	24 shall evaluate publicly available analyses and studies
3153	3153	25 of the potential market size for utility-scale
3154	3154	26 renewable energy long-term purchase agreements by
3155	3155
3156	3156
3157	3157
3158	3158
3159	3159
3160	3160	SB1442 - 87 - LRB104 11424 BDA 21512 b
3161	3161
3162	3162
3163	3163	SB1442- 88 -LRB104 11424 BDA 21512 b SB1442 - 88 - LRB104 11424 BDA 21512 b
3164	3164	SB1442 - 88 - LRB104 11424 BDA 21512 b
3165	3165	1 commercial and industrial energy customers and make
3166	3166	2 that report publicly available. If demand for
3167	3167	3 participation in the self-direct renewable portfolio
3168	3168	4 standard compliance program exceeds availability, the
3169	3169	5 Agency shall ensure participation is evenly split
3170	3170	6 between commercial and industrial users to the extent
3171	3171	7 there is sufficient demand from both customer classes.
3172	3172	8 Each renewable energy credit procured pursuant to this
3173	3173	9 subparagraph (R) by a self-direct customer shall
3174	3174	10 reduce the total volume of renewable energy credits
3175	3175	11 the Agency is otherwise required to procure from new
3176	3176	12 utility-scale projects pursuant to subparagraph (C) of
3177	3177	13 paragraph (1) of this subsection (c) on behalf of
3178	3178	14 contracting utilities where the eligible self-direct
3179	3179	15 customer is located. The self-direct customer shall
3180	3180	16 file an annual compliance report with the Agency
3181	3181	17 pursuant to terms established by the Agency through
3182	3182	18 its long-term renewable resources procurement plan to
3183	3183	19 be eligible for participation in this program.
3184	3184	20 Customers must provide the Agency with their most
3185	3185	21 recent electricity billing statements or other
3186	3186	22 information deemed necessary by the Agency to
3187	3187	23 demonstrate they are an eligible self-direct customer.
3188	3188	24 (4) The Commission shall approve a reduction in
3189	3189	25 the volumetric charges collected pursuant to Section
3190	3190	26 16-108 of the Public Utilities Act for approved
3191	3191
3192	3192
3193	3193
3194	3194
3195	3195
3196	3196	SB1442 - 88 - LRB104 11424 BDA 21512 b
3197	3197
3198	3198
3199	3199	SB1442- 89 -LRB104 11424 BDA 21512 b SB1442 - 89 - LRB104 11424 BDA 21512 b
3200	3200	SB1442 - 89 - LRB104 11424 BDA 21512 b
3201	3201	1 eligible self-direct customers equivalent to the
3202	3202	2 anticipated cost of renewable energy credit deliveries
3203	3203	3 under contracts for new utility-scale wind and new
3204	3204	4 utility-scale solar entered for each delivery year
3205	3205	5 after the large energy customer begins retiring
3206	3206	6 eligible new utility scale renewable energy credits
3207	3207	7 for self-compliance. The self-direct credit amount
3208	3208	8 shall be determined annually and is equal to the
3209	3209	9 estimated portion of the cost authorized by
3210	3210	10 subparagraph (E) of paragraph (1) of this subsection
3211	3211	11 (c) that supported the annual procurement of
3212	3212	12 utility-scale renewable energy credits in the prior
3213	3213	13 delivery year using a methodology described in the
3214	3214	14 long-term renewable resources procurement plan,
3215	3215	15 expressed on a per kilowatthour basis, and does not
3216	3216	16 include (i) costs associated with any contracts
3217	3217	17 entered into before the delivery year in which the
3218	3218	18 customer files the initial compliance report to be
3219	3219	19 eligible for participation in the self-direct program,
3220	3220	20 and (ii) costs associated with procuring renewable
3221	3221	21 energy credits through existing and future contracts
3222	3222	22 through the Adjustable Block Program, subsection (c-5)
3223	3223	23 of this Section 1-75, and the Solar for All Program.
3224	3224	24 The Agency shall assist the Commission in determining
3225	3225	25 the current and future costs. The Agency must
3226	3226	26 determine the self-direct credit amount for new and
3227	3227
3228	3228
3229	3229
3230	3230
3231	3231
3232	3232	SB1442 - 89 - LRB104 11424 BDA 21512 b
3233	3233
3234	3234
3235	3235	SB1442- 90 -LRB104 11424 BDA 21512 b SB1442 - 90 - LRB104 11424 BDA 21512 b
3236	3236	SB1442 - 90 - LRB104 11424 BDA 21512 b
3237	3237	1 existing eligible self-direct customers and submit
3238	3238	2 this to the Commission in an annual compliance filing.
3239	3239	3 The Commission must approve the self-direct credit
3240	3240	4 amount by June 1, 2023 and June 1 of each delivery year
3241	3241	5 thereafter.
3242	3242	6 (5) Customers described in this subparagraph (R)
3243	3243	7 shall apply, on a form developed by the Agency, to the
3244	3244	8 Agency to be designated as a self-direct eligible
3245	3245	9 customer. Once the Agency determines that a
3246	3246	10 self-direct customer is eligible for participation in
3247	3247	11 the program, the self-direct customer will remain
3248	3248	12 eligible until the end of the term of the contract.
3249	3249	13 Thereafter, application may be made not less than 12
3250	3250	14 months before the filing date of the long-term
3251	3251	15 renewable resources procurement plan described in this
3252	3252	16 Act. At a minimum, such application shall contain the
3253	3253	17 following:
3254	3254	18 (i) the customer's certification that, at the
3255	3255	19 time of the customer's application, the customer
3256	3256	20 qualifies to be a self-direct eligible customer,
3257	3257	21 including documents demonstrating that
3258	3258	22 qualification;
3259	3259	23 (ii) the customer's certification that the
3260	3260	24 customer has entered into or will enter into by
3261	3261	25 the beginning of the applicable procurement year,
3262	3262	26 one or more bilateral contracts for new wind
3263	3263
3264	3264
3265	3265
3266	3266
3267	3267
3268	3268	SB1442 - 90 - LRB104 11424 BDA 21512 b
3269	3269
3270	3270
3271	3271	SB1442- 91 -LRB104 11424 BDA 21512 b SB1442 - 91 - LRB104 11424 BDA 21512 b
3272	3272	SB1442 - 91 - LRB104 11424 BDA 21512 b
3273	3273	1 projects or new photovoltaic projects, including
3274	3274	2 supporting documentation;
3275	3275	3 (iii) certification that the contract or
3276	3276	4 contracts for new renewable energy resources are
3277	3277	5 long-term contracts with term lengths of at least
3278	3278	6 10 years, including supporting documentation;
3279	3279	7 (iv) certification of the quantities of
3280	3280	8 renewable energy credits that the customer will
3281	3281	9 purchase each year under such contract or
3282	3282	10 contracts, including supporting documentation;
3283	3283	11 (v) proof that the contract is sufficient to
3284	3284	12 produce renewable energy credits to be equivalent
3285	3285	13 in volume to at least 40% of the large energy
3286	3286	14 customer's usage from the previous delivery year,
3287	3287	15 measured to the nearest megawatt-hour; and
3288	3288	16 (vi) certification that the customer intends
3289	3289	17 to maintain the contract for the duration of the
3290	3290	18 length of the contract.
3291	3291	19 (6) If a customer receives the self-direct credit
3292	3292	20 but fails to properly procure and retire renewable
3293	3293	21 energy credits as required under this subparagraph
3294	3294	22 (R), the Commission, on petition from the Agency and
3295	3295	23 after notice and hearing, may direct such customer's
3296	3296	24 utility to recover the cost of the wrongfully received
3297	3297	25 self-direct credits plus interest through an adder to
3298	3298	26 charges assessed pursuant to Section 16-108 of the
3299	3299
3300	3300
3301	3301
3302	3302
3303	3303
3304	3304	SB1442 - 91 - LRB104 11424 BDA 21512 b
3305	3305
3306	3306
3307	3307	SB1442- 92 -LRB104 11424 BDA 21512 b SB1442 - 92 - LRB104 11424 BDA 21512 b
3308	3308	SB1442 - 92 - LRB104 11424 BDA 21512 b
3309	3309	1 Public Utilities Act. Self-direct customers who
3310	3310	2 knowingly fail to properly procure and retire
3311	3311	3 renewable energy credits and do not notify the Agency
3312	3312	4 are ineligible for continued participation in the
3313	3313	5 self-direct renewable portfolio standard compliance
3314	3314	6 program.
3315	3315	7 (2) (Blank).
3316	3316	8 (3) (Blank).
3317	3317	9 (4) The electric utility shall retire all renewable
3318	3318	10 energy credits used to comply with the standard.
3319	3319	11 (5) Beginning with the 2010 delivery year and ending
3320	3320	12 June 1, 2017, an electric utility subject to this
3321	3321	13 subsection (c) shall apply the lesser of the maximum
3322	3322	14 alternative compliance payment rate or the most recent
3323	3323	15 estimated alternative compliance payment rate for its
3324	3324	16 service territory for the corresponding compliance period,
3325	3325	17 established pursuant to subsection (d) of Section 16-115D
3326	3326	18 of the Public Utilities Act to its retail customers that
3327	3327	19 take service pursuant to the electric utility's hourly
3328	3328	20 pricing tariff or tariffs. The electric utility shall
3329	3329	21 retain all amounts collected as a result of the
3330	3330	22 application of the alternative compliance payment rate or
3331	3331	23 rates to such customers, and, beginning in 2011, the
3332	3332	24 utility shall include in the information provided under
3333	3333	25 item (1) of subsection (d) of Section 16-111.5 of the
3334	3334	26 Public Utilities Act the amounts collected under the
3335	3335
3336	3336
3337	3337
3338	3338
3339	3339
3340	3340	SB1442 - 92 - LRB104 11424 BDA 21512 b
3341	3341
3342	3342
3343	3343	SB1442- 93 -LRB104 11424 BDA 21512 b SB1442 - 93 - LRB104 11424 BDA 21512 b
3344	3344	SB1442 - 93 - LRB104 11424 BDA 21512 b
3345	3345	1 alternative compliance payment rate or rates for the prior
3346	3346	2 year ending May 31. Notwithstanding any limitation on the
3347	3347	3 procurement of renewable energy resources imposed by item
3348	3348	4 (2) of this subsection (c), the Agency shall increase its
3349	3349	5 spending on the purchase of renewable energy resources to
3350	3350	6 be procured by the electric utility for the next plan year
3351	3351	7 by an amount equal to the amounts collected by the utility
3352	3352	8 under the alternative compliance payment rate or rates in
3353	3353	9 the prior year ending May 31.
3354	3354	10 (6) The electric utility shall be entitled to recover
3355	3355	11 all of its costs associated with the procurement of
3356	3356	12 renewable energy credits under plans approved under this
3357	3357	13 Section and Section 16-111.5 of the Public Utilities Act.
3358	3358	14 These costs shall include associated reasonable expenses
3359	3359	15 for implementing the procurement programs, including, but
3360	3360	16 not limited to, the costs of administering and evaluating
3361	3361	17 the Adjustable Block program, through an automatic
3362	3362	18 adjustment clause tariff in accordance with subsection (k)
3363	3363	19 of Section 16-108 of the Public Utilities Act.
3364	3364	20 (7) Renewable energy credits procured from new
3365	3365	21 photovoltaic projects or new distributed renewable energy
3366	3366	22 generation devices under this Section after June 1, 2017
3367	3367	23 (the effective date of Public Act 99-906) must be procured
3368	3368	24 from devices installed by a qualified person in compliance
3369	3369	25 with the requirements of Section 16-128A of the Public
3370	3370	26 Utilities Act and any rules or regulations adopted
3371	3371
3372	3372
3373	3373
3374	3374
3375	3375
3376	3376	SB1442 - 93 - LRB104 11424 BDA 21512 b
3377	3377
3378	3378
3379	3379	SB1442- 94 -LRB104 11424 BDA 21512 b SB1442 - 94 - LRB104 11424 BDA 21512 b
3380	3380	SB1442 - 94 - LRB104 11424 BDA 21512 b
3381	3381	1 thereunder.
3382	3382	2 In meeting the renewable energy requirements of this
3383	3383	3 subsection (c), to the extent feasible and consistent with
3384	3384	4 State and federal law, the renewable energy credit
3385	3385	5 procurements, Adjustable Block solar program, and
3386	3386	6 community renewable generation program shall provide
3387	3387	7 employment opportunities for all segments of the
3388	3388	8 population and workforce, including minority-owned and
3389	3389	9 female-owned business enterprises, and shall not,
3390	3390	10 consistent with State and federal law, discriminate based
3391	3391	11 on race or socioeconomic status.
3392	3392	12 (c-5) Procurement of renewable energy credits from new
3393	3393	13 renewable energy facilities installed at or adjacent to the
3394	3394	14 sites of electric generating facilities that burn or burned
3395	3395	15 coal as their primary fuel source.
3396	3396	16 (1) In addition to the procurement of renewable energy
3397	3397	17 credits pursuant to long-term renewable resources
3398	3398	18 procurement plans in accordance with subsection (c) of
3399	3399	19 this Section and Section 16-111.5 of the Public Utilities
3400	3400	20 Act, the Agency shall conduct procurement events in
3401	3401	21 accordance with this subsection (c-5) for the procurement
3402	3402	22 by electric utilities that served more than 300,000 retail
3403	3403	23 customers in this State as of January 1, 2019 of renewable
3404	3404	24 energy credits from new renewable energy facilities to be
3405	3405	25 installed at or adjacent to the sites of electric
3406	3406	26 generating facilities that, as of January 1, 2016, burned
3407	3407
3408	3408
3409	3409
3410	3410
3411	3411
3412	3412	SB1442 - 94 - LRB104 11424 BDA 21512 b
3413	3413
3414	3414
3415	3415	SB1442- 95 -LRB104 11424 BDA 21512 b SB1442 - 95 - LRB104 11424 BDA 21512 b
3416	3416	SB1442 - 95 - LRB104 11424 BDA 21512 b
3417	3417	1 coal as their primary fuel source and meet the other
3418	3418	2 criteria specified in this subsection (c-5). For purposes
3419	3419	3 of this subsection (c-5), "new renewable energy facility"
3420	3420	4 means a new utility-scale solar project as defined in this
3421	3421	5 Section 1-75. The renewable energy credits procured
3422	3422	6 pursuant to this subsection (c-5) may be included or
3423	3423	7 counted for purposes of compliance with the amounts of
3424	3424	8 renewable energy credits required to be procured pursuant
3425	3425	9 to subsection (c) of this Section to the extent that there
3426	3426	10 are otherwise shortfalls in compliance with such
3427	3427	11 requirements. The procurement of renewable energy credits
3428	3428	12 by electric utilities pursuant to this subsection (c-5)
3429	3429	13 shall be funded solely by revenues collected from the Coal
3430	3430	14 to Solar and Energy Storage Initiative Charge provided for
3431	3431	15 in this subsection (c-5) and subsection (i-5) of Section
3432	3432	16 16-108 of the Public Utilities Act, shall not be funded by
3433	3433	17 revenues collected through any of the other funding
3434	3434	18 mechanisms provided for in subsection (c) of this Section,
3435	3435	19 and shall not be subject to the limitation imposed by
3436	3436	20 subsection (c) on charges to retail customers for costs to
3437	3437	21 procure renewable energy resources pursuant to subsection
3438	3438	22 (c), and shall not be subject to any other requirements or
3439	3439	23 limitations of subsection (c).
3440	3440	24 (2) The Agency shall conduct 2 procurement events to
3441	3441	25 select owners of electric generating facilities meeting
3442	3442	26 the eligibility criteria specified in this subsection
3443	3443
3444	3444
3445	3445
3446	3446
3447	3447
3448	3448	SB1442 - 95 - LRB104 11424 BDA 21512 b
3449	3449
3450	3450
3451	3451	SB1442- 96 -LRB104 11424 BDA 21512 b SB1442 - 96 - LRB104 11424 BDA 21512 b
3452	3452	SB1442 - 96 - LRB104 11424 BDA 21512 b
3453	3453	1 (c-5) to enter into long-term contracts to sell renewable
3454	3454	2 energy credits to electric utilities serving more than
3455	3455	3 300,000 retail customers in this State as of January 1,
3456	3456	4 2019. The first procurement event shall be conducted no
3457	3457	5 later than March 31, 2022, unless the Agency elects to
3458	3458	6 delay it, until no later than May 1, 2022, due to its
3459	3459	7 overall volume of work, and shall be to select owners of
3460	3460	8 electric generating facilities located in this State and
3461	3461	9 south of federal Interstate Highway 80 that meet the
3462	3462	10 eligibility criteria specified in this subsection (c-5).
3463	3463	11 The second procurement event shall be conducted no sooner
3464	3464	12 than September 30, 2022 and no later than October 31, 2022
3465	3465	13 and shall be to select owners of electric generating
3466	3466	14 facilities located anywhere in this State that meet the
3467	3467	15 eligibility criteria specified in this subsection (c-5).
3468	3468	16 The Agency shall establish and announce a time period,
3469	3469	17 which shall begin no later than 30 days prior to the
3470	3470	18 scheduled date for the procurement event, during which
3471	3471	19 applicants may submit applications to be selected as
3472	3472	20 suppliers of renewable energy credits pursuant to this
3473	3473	21 subsection (c-5). The eligibility criteria for selection
3474	3474	22 as a supplier of renewable energy credits pursuant to this
3475	3475	23 subsection (c-5) shall be as follows:
3476	3476	24 (A) The applicant owns an electric generating
3477	3477	25 facility located in this State that: (i) as of January
3478	3478	26 1, 2016, burned coal as its primary fuel to generate
3479	3479
3480	3480
3481	3481
3482	3482
3483	3483
3484	3484	SB1442 - 96 - LRB104 11424 BDA 21512 b
3485	3485
3486	3486
3487	3487	SB1442- 97 -LRB104 11424 BDA 21512 b SB1442 - 97 - LRB104 11424 BDA 21512 b
3488	3488	SB1442 - 97 - LRB104 11424 BDA 21512 b
3489	3489	1 electricity; and (ii) has, or had prior to retirement,
3490	3490	2 an electric generating capacity of at least 150
3491	3491	3 megawatts. The electric generating facility can be
3492	3492	4 either: (i) retired as of the date of the procurement
3493	3493	5 event; or (ii) still operating as of the date of the
3494	3494	6 procurement event.
3495	3495	7 (B) The applicant is not (i) an electric
3496	3496	8 cooperative as defined in Section 3-119 of the Public
3497	3497	9 Utilities Act, or (ii) an entity described in
3498	3498	10 subsection (b)(1) of Section 3-105 of the Public
3499	3499	11 Utilities Act, or an association or consortium of or
3500	3500	12 an entity owned by entities described in (i) or (ii);
3501	3501	13 and the coal-fueled electric generating facility was
3502	3502	14 at one time owned, in whole or in part, by a public
3503	3503	15 utility as defined in Section 3-105 of the Public
3504	3504	16 Utilities Act.
3505	3505	17 (C) If participating in the first procurement
3506	3506	18 event, the applicant proposes and commits to construct
3507	3507	19 and operate, at the site, and if necessary for
3508	3508	20 sufficient space on property adjacent to the existing
3509	3509	21 property, at which the electric generating facility
3510	3510	22 identified in paragraph (A) is located: (i) a new
3511	3511	23 renewable energy facility of at least 20 megawatts but
3512	3512	24 no more than 100 megawatts of electric generating
3513	3513	25 capacity, and (ii) an energy storage facility having a
3514	3514	26 storage capacity equal to at least 2 megawatts and at
3515	3515
3516	3516
3517	3517
3518	3518
3519	3519
3520	3520	SB1442 - 97 - LRB104 11424 BDA 21512 b
3521	3521
3522	3522
3523	3523	SB1442- 98 -LRB104 11424 BDA 21512 b SB1442 - 98 - LRB104 11424 BDA 21512 b
3524	3524	SB1442 - 98 - LRB104 11424 BDA 21512 b
3525	3525	1 most 10 megawatts. If participating in the second
3526	3526	2 procurement event, the applicant proposes and commits
3527	3527	3 to construct and operate, at the site, and if
3528	3528	4 necessary for sufficient space on property adjacent to
3529	3529	5 the existing property, at which the electric
3530	3530	6 generating facility identified in paragraph (A) is
3531	3531	7 located: (i) a new renewable energy facility of at
3532	3532	8 least 5 megawatts but no more than 20 megawatts of
3533	3533	9 electric generating capacity, and (ii) an energy
3534	3534	10 storage facility having a storage capacity equal to at
3535	3535	11 least 0.5 megawatts and at most one megawatt.
3536	3536	12 (D) The applicant agrees that the new renewable
3537	3537	13 energy facility and the energy storage facility will
3538	3538	14 be constructed or installed by a qualified entity or
3539	3539	15 entities in compliance with the requirements of
3540	3540	16 subsection (g) of Section 16-128A of the Public
3541	3541	17 Utilities Act and any rules adopted thereunder.
3542	3542	18 (E) The applicant agrees that personnel operating
3543	3543	19 the new renewable energy facility and the energy
3544	3544	20 storage facility will have the requisite skills,
3545	3545	21 knowledge, training, experience, and competence, which
3546	3546	22 may be demonstrated by completion or current
3547	3547	23 participation and ultimate completion by employees of
3548	3548	24 an accredited or otherwise recognized apprenticeship
3549	3549	25 program for the employee's particular craft, trade, or
3550	3550	26 skill, including through training and education
3551	3551
3552	3552
3553	3553
3554	3554
3555	3555
3556	3556	SB1442 - 98 - LRB104 11424 BDA 21512 b
3557	3557
3558	3558
3559	3559	SB1442- 99 -LRB104 11424 BDA 21512 b SB1442 - 99 - LRB104 11424 BDA 21512 b
3560	3560	SB1442 - 99 - LRB104 11424 BDA 21512 b
3561	3561	1 courses and opportunities offered by the owner to
3562	3562	2 employees of the coal-fueled electric generating
3563	3563	3 facility or by previous employment experience
3564	3564	4 performing the employee's particular work skill or
3565	3565	5 function.
3566	3566	6 (F) The applicant commits that not less than the
3567	3567	7 prevailing wage, as determined pursuant to the
3568	3568	8 Prevailing Wage Act, will be paid to the applicant's
3569	3569	9 employees engaged in construction activities
3570	3570	10 associated with the new renewable energy facility and
3571	3571	11 the new energy storage facility and to the employees
3572	3572	12 of applicant's contractors engaged in construction
3573	3573	13 activities associated with the new renewable energy
3574	3574	14 facility and the new energy storage facility, and
3575	3575	15 that, on or before the commercial operation date of
3576	3576	16 the new renewable energy facility, the applicant shall
3577	3577	17 file a report with the Agency certifying that the
3578	3578	18 requirements of this subparagraph (F) have been met.
3579	3579	19 (G) The applicant commits that if selected, it
3580	3580	20 will negotiate a project labor agreement for the
3581	3581	21 construction of the new renewable energy facility and
3582	3582	22 associated energy storage facility that includes
3583	3583	23 provisions requiring the parties to the agreement to
3584	3584	24 work together to establish diversity threshold
3585	3585	25 requirements and to ensure best efforts to meet
3586	3586	26 diversity targets, improve diversity at the applicable
3587	3587
3588	3588
3589	3589
3590	3590
3591	3591
3592	3592	SB1442 - 99 - LRB104 11424 BDA 21512 b
3593	3593
3594	3594
3595	3595	SB1442- 100 -LRB104 11424 BDA 21512 b SB1442 - 100 - LRB104 11424 BDA 21512 b
3596	3596	SB1442 - 100 - LRB104 11424 BDA 21512 b
3597	3597	1 job site, create diverse apprenticeship opportunities,
3598	3598	2 and create opportunities to employ former coal-fired
3599	3599	3 power plant workers.
3600	3600	4 (H) The applicant commits to enter into a contract
3601	3601	5 or contracts for the applicable duration to provide
3602	3602	6 specified numbers of renewable energy credits each
3603	3603	7 year from the new renewable energy facility to
3604	3604	8 electric utilities that served more than 300,000
3605	3605	9 retail customers in this State as of January 1, 2019,
3606	3606	10 at a price of $30 per renewable energy credit. The
3607	3607	11 price per renewable energy credit shall be fixed at
3608	3608	12 $30 for the applicable duration and the renewable
3609	3609	13 energy credits shall not be indexed renewable energy
3610	3610	14 credits as provided for in item (v) of subparagraph
3611	3611	15 (G) of paragraph (1) of subsection (c) of Section 1-75
3612	3612	16 of this Act. The applicable duration of each contract
3613	3613	17 shall be 20 years, unless the applicant is physically
3614	3614	18 interconnected to the PJM Interconnection, LLC
3615	3615	19 transmission grid and had a generating capacity of at
3616	3616	20 least 1,200 megawatts as of January 1, 2021, in which
3617	3617	21 case the applicable duration of the contract shall be
3618	3618	22 15 years.
3619	3619	23 (I) The applicant's application is certified by an
3620	3620	24 officer of the applicant and by an officer of the
3621	3621	25 applicant's ultimate parent company, if any.
3622	3622	26 (3) An applicant may submit applications to contract
3623	3623
3624	3624
3625	3625
3626	3626
3627	3627
3628	3628	SB1442 - 100 - LRB104 11424 BDA 21512 b
3629	3629
3630	3630
3631	3631	SB1442- 101 -LRB104 11424 BDA 21512 b SB1442 - 101 - LRB104 11424 BDA 21512 b
3632	3632	SB1442 - 101 - LRB104 11424 BDA 21512 b
3633	3633	1 to supply renewable energy credits from more than one new
3634	3634	2 renewable energy facility to be constructed at or adjacent
3635	3635	3 to one or more qualifying electric generating facilities
3636	3636	4 owned by the applicant. The Agency may select new
3637	3637	5 renewable energy facilities to be located at or adjacent
3638	3638	6 to the sites of more than one qualifying electric
3639	3639	7 generation facility owned by an applicant to contract with
3640	3640	8 electric utilities to supply renewable energy credits from
3641	3641	9 such facilities.
3642	3642	10 (4) The Agency shall assess fees to each applicant to
3643	3643	11 recover the Agency's costs incurred in receiving and
3644	3644	12 evaluating applications, conducting the procurement event,
3645	3645	13 developing contracts for sale, delivery and purchase of
3646	3646	14 renewable energy credits, and monitoring the
3647	3647	15 administration of such contracts, as provided for in this
3648	3648	16 subsection (c-5), including fees paid to a procurement
3649	3649	17 administrator retained by the Agency for one or more of
3650	3650	18 these purposes.
3651	3651	19 (5) The Agency shall select the applicants and the new
3652	3652	20 renewable energy facilities to contract with electric
3653	3653	21 utilities to supply renewable energy credits in accordance
3654	3654	22 with this subsection (c-5). In the first procurement
3655	3655	23 event, the Agency shall select applicants and new
3656	3656	24 renewable energy facilities to supply renewable energy
3657	3657	25 credits, at a price of $30 per renewable energy credit,
3658	3658	26 aggregating to no less than 400,000 renewable energy
3659	3659
3660	3660
3661	3661
3662	3662
3663	3663
3664	3664	SB1442 - 101 - LRB104 11424 BDA 21512 b
3665	3665
3666	3666
3667	3667	SB1442- 102 -LRB104 11424 BDA 21512 b SB1442 - 102 - LRB104 11424 BDA 21512 b
3668	3668	SB1442 - 102 - LRB104 11424 BDA 21512 b
3669	3669	1 credits per year for the applicable duration, assuming
3670	3670	2 sufficient qualifying applications to supply, in the
3671	3671	3 aggregate, at least that amount of renewable energy
3672	3672	4 credits per year; and not more than 580,000 renewable
3673	3673	5 energy credits per year for the applicable duration. In
3674	3674	6 the second procurement event, the Agency shall select
3675	3675	7 applicants and new renewable energy facilities to supply
3676	3676	8 renewable energy credits, at a price of $30 per renewable
3677	3677	9 energy credit, aggregating to no more than 625,000
3678	3678	10 renewable energy credits per year less the amount of
3679	3679	11 renewable energy credits each year contracted for as a
3680	3680	12 result of the first procurement event, for the applicable
3681	3681	13 durations. The number of renewable energy credits to be
3682	3682	14 procured as specified in this paragraph (5) shall not be
3683	3683	15 reduced based on renewable energy credits procured in the
3684	3684	16 self-direct renewable energy credit compliance program
3685	3685	17 established pursuant to subparagraph (R) of paragraph (1)
3686	3686	18 of subsection (c) of Section 1-75.
3687	3687	19 (6) The obligation to purchase renewable energy
3688	3688	20 credits from the applicants and their new renewable energy
3689	3689	21 facilities selected by the Agency shall be allocated to
3690	3690	22 the electric utilities based on their respective
3691	3691	23 percentages of kilowatthours delivered to delivery
3692	3692	24 services customers to the aggregate kilowatthour
3693	3693	25 deliveries by the electric utilities to delivery services
3694	3694	26 customers for the year ended December 31, 2021. In order
3695	3695
3696	3696
3697	3697
3698	3698
3699	3699
3700	3700	SB1442 - 102 - LRB104 11424 BDA 21512 b
3701	3701
3702	3702
3703	3703	SB1442- 103 -LRB104 11424 BDA 21512 b SB1442 - 103 - LRB104 11424 BDA 21512 b
3704	3704	SB1442 - 103 - LRB104 11424 BDA 21512 b
3705	3705	1 to achieve these allocation percentages between or among
3706	3706	2 the electric utilities, the Agency shall require each
3707	3707	3 applicant that is selected in the procurement event to
3708	3708	4 enter into a contract with each electric utility for the
3709	3709	5 sale and purchase of renewable energy credits from each
3710	3710	6 new renewable energy facility to be constructed and
3711	3711	7 operated by the applicant, with the sale and purchase
3712	3712	8 obligations under the contracts to aggregate to the total
3713	3713	9 number of renewable energy credits per year to be supplied
3714	3714	10 by the applicant from the new renewable energy facility.
3715	3715	11 (7) The Agency shall submit its proposed selection of
3716	3716	12 applicants, new renewable energy facilities to be
3717	3717	13 constructed, and renewable energy credit amounts for each
3718	3718	14 procurement event to the Commission for approval. The
3719	3719	15 Commission shall, within 2 business days after receipt of
3720	3720	16 the Agency's proposed selections, approve the proposed
3721	3721	17 selections if it determines that the applicants and the
3722	3722	18 new renewable energy facilities to be constructed meet the
3723	3723	19 selection criteria set forth in this subsection (c-5) and
3724	3724	20 that the Agency seeks approval for contracts of applicable
3725	3725	21 durations aggregating to no more than the maximum amount
3726	3726	22 of renewable energy credits per year authorized by this
3727	3727	23 subsection (c-5) for the procurement event, at a price of
3728	3728	24 $30 per renewable energy credit.
3729	3729	25 (8) The Agency, in conjunction with its procurement
3730	3730	26 administrator if one is retained, the electric utilities,
3731	3731
3732	3732
3733	3733
3734	3734
3735	3735
3736	3736	SB1442 - 103 - LRB104 11424 BDA 21512 b
3737	3737
3738	3738
3739	3739	SB1442- 104 -LRB104 11424 BDA 21512 b SB1442 - 104 - LRB104 11424 BDA 21512 b
3740	3740	SB1442 - 104 - LRB104 11424 BDA 21512 b
3741	3741	1 and potential applicants for contracts to produce and
3742	3742	2 supply renewable energy credits pursuant to this
3743	3743	3 subsection (c-5), shall develop a standard form contract
3744	3744	4 for the sale, delivery and purchase of renewable energy
3745	3745	5 credits pursuant to this subsection (c-5). Each contract
3746	3746	6 resulting from the first procurement event shall allow for
3747	3747	7 a commercial operation date for the new renewable energy
3748	3748	8 facility of either June 1, 2023 or June 1, 2024, with such
3749	3749	9 dates subject to adjustment as provided in this paragraph.
3750	3750	10 Each contract resulting from the second procurement event
3751	3751	11 shall provide for a commercial operation date on June 1
3752	3752	12 next occurring up to 48 months after execution of the
3753	3753	13 contract. Each contract shall provide that the owner shall
3754	3754	14 receive payments for renewable energy credits for the
3755	3755	15 applicable durations beginning with the commercial
3756	3756	16 operation date of the new renewable energy facility. The
3757	3757	17 form contract shall provide for adjustments to the
3758	3758	18 commercial operation and payment start dates as needed due
3759	3759	19 to any delays in completing the procurement and
3760	3760	20 contracting processes, in finalizing interconnection
3761	3761	21 agreements and installing interconnection facilities, and
3762	3762	22 in obtaining other necessary governmental permits and
3763	3763	23 approvals. The form contract shall be, to the maximum
3764	3764	24 extent possible, consistent with standard electric
3765	3765	25 industry contracts for sale, delivery, and purchase of
3766	3766	26 renewable energy credits while taking into account the
3767	3767
3768	3768
3769	3769
3770	3770
3771	3771
3772	3772	SB1442 - 104 - LRB104 11424 BDA 21512 b
3773	3773
3774	3774
3775	3775	SB1442- 105 -LRB104 11424 BDA 21512 b SB1442 - 105 - LRB104 11424 BDA 21512 b
3776	3776	SB1442 - 105 - LRB104 11424 BDA 21512 b
3777	3777	1 specific requirements of this subsection (c-5). The form
3778	3778	2 contract shall provide for over-delivery and
3779	3779	3 under-delivery of renewable energy credits within
3780	3780	4 reasonable ranges during each 12-month period and penalty,
3781	3781	5 default, and enforcement provisions for failure of the
3782	3782	6 selling party to deliver renewable energy credits as
3783	3783	7 specified in the contract and to comply with the
3784	3784	8 requirements of this subsection (c-5). The standard form
3785	3785	9 contract shall specify that all renewable energy credits
3786	3786	10 delivered to the electric utility pursuant to the contract
3787	3787	11 shall be retired. The Agency shall make the proposed
3788	3788	12 contracts available for a reasonable period for comment by
3789	3789	13 potential applicants, and shall publish the final form
3790	3790	14 contract at least 30 days before the date of the first
3791	3791	15 procurement event.
3792	3792	16 (9) Coal to Solar and Energy Storage Initiative
3793	3793	17 Charge.
3794	3794	18 (A) By no later than July 1, 2022, each electric
3795	3795	19 utility that served more than 300,000 retail customers
3796	3796	20 in this State as of January 1, 2019 shall file a tariff
3797	3797	21 with the Commission for the billing and collection of
3798	3798	22 a Coal to Solar and Energy Storage Initiative Charge
3799	3799	23 in accordance with subsection (i-5) of Section 16-108
3800	3800	24 of the Public Utilities Act, with such tariff to be
3801	3801	25 effective, following review and approval or
3802	3802	26 modification by the Commission, beginning January 1,
3803	3803
3804	3804
3805	3805
3806	3806
3807	3807
3808	3808	SB1442 - 105 - LRB104 11424 BDA 21512 b
3809	3809
3810	3810
3811	3811	SB1442- 106 -LRB104 11424 BDA 21512 b SB1442 - 106 - LRB104 11424 BDA 21512 b
3812	3812	SB1442 - 106 - LRB104 11424 BDA 21512 b
3813	3813	1 2023. The tariff shall provide for the calculation and
3814	3814	2 setting of the electric utility's Coal to Solar and
3815	3815	3 Energy Storage Initiative Charge to collect revenues
3816	3816	4 estimated to be sufficient, in the aggregate, (i) to
3817	3817	5 enable the electric utility to pay for the renewable
3818	3818	6 energy credits it has contracted to purchase in the
3819	3819	7 delivery year beginning June 1, 2023 and each delivery
3820	3820	8 year thereafter from new renewable energy facilities
3821	3821	9 located at the sites of qualifying electric generating
3822	3822	10 facilities, and (ii) to fund the grant payments to be
3823	3823	11 made in each delivery year by the Department of
3824	3824	12 Commerce and Economic Opportunity, or any successor
3825	3825	13 department or agency, which shall be referred to in
3826	3826	14 this subsection (c-5) as the Department, pursuant to
3827	3827	15 paragraph (10) of this subsection (c-5). The electric
3828	3828	16 utility's tariff shall provide for the billing and
3829	3829	17 collection of the Coal to Solar and Energy Storage
3830	3830	18 Initiative Charge on each kilowatthour of electricity
3831	3831	19 delivered to its delivery services customers within
3832	3832	20 its service territory and shall provide for an annual
3833	3833	21 reconciliation of revenues collected with actual
3834	3834	22 costs, in accordance with subsection (i-5) of Section
3835	3835	23 16-108 of the Public Utilities Act.
3836	3836	24 (B) Each electric utility shall remit on a monthly
3837	3837	25 basis to the State Treasurer, for deposit in the Coal
3838	3838	26 to Solar and Energy Storage Initiative Fund provided
3839	3839
3840	3840
3841	3841
3842	3842
3843	3843
3844	3844	SB1442 - 106 - LRB104 11424 BDA 21512 b
3845	3845
3846	3846
3847	3847	SB1442- 107 -LRB104 11424 BDA 21512 b SB1442 - 107 - LRB104 11424 BDA 21512 b
3848	3848	SB1442 - 107 - LRB104 11424 BDA 21512 b
3849	3849	1 for in this subsection (c-5), the electric utility's
3850	3850	2 collections of the Coal to Solar and Energy Storage
3851	3851	3 Initiative Charge in the amount estimated to be needed
3852	3852	4 by the Department for grant payments pursuant to grant
3853	3853	5 contracts entered into by the Department pursuant to
3854	3854	6 paragraph (10) of this subsection (c-5).
3855	3855	7 (10) Coal to Solar and Energy Storage Initiative Fund.
3856	3856	8 (A) The Coal to Solar and Energy Storage
3857	3857	9 Initiative Fund is established as a special fund in
3858	3858	10 the State treasury. The Coal to Solar and Energy
3859	3859	11 Storage Initiative Fund is authorized to receive, by
3860	3860	12 statutory deposit, that portion specified in item (B)
3861	3861	13 of paragraph (9) of this subsection (c-5) of moneys
3862	3862	14 collected by electric utilities through imposition of
3863	3863	15 the Coal to Solar and Energy Storage Initiative Charge
3864	3864	16 required by this subsection (c-5). The Coal to Solar
3865	3865	17 and Energy Storage Initiative Fund shall be
3866	3866	18 administered by the Department to provide grants to
3867	3867	19 support the installation and operation of energy
3868	3868	20 storage facilities at the sites of qualifying electric
3869	3869	21 generating facilities meeting the criteria specified
3870	3870	22 in this paragraph (10).
3871	3871	23 (B) The Coal to Solar and Energy Storage
3872	3872	24 Initiative Fund shall not be subject to sweeps,
3873	3873	25 administrative charges, or chargebacks, including, but
3874	3874	26 not limited to, those authorized under Section 8h of
3875	3875
3876	3876
3877	3877
3878	3878
3879	3879
3880	3880	SB1442 - 107 - LRB104 11424 BDA 21512 b
3881	3881
3882	3882
3883	3883	SB1442- 108 -LRB104 11424 BDA 21512 b SB1442 - 108 - LRB104 11424 BDA 21512 b
3884	3884	SB1442 - 108 - LRB104 11424 BDA 21512 b
3885	3885	1 the State Finance Act, that would in any way result in
3886	3886	2 the transfer of those funds from the Coal to Solar and
3887	3887	3 Energy Storage Initiative Fund to any other fund of
3888	3888	4 this State or in having any such funds utilized for any
3889	3889	5 purpose other than the express purposes set forth in
3890	3890	6 this paragraph (10).
3891	3891	7 (C) The Department shall utilize up to
3892	3892	8 $280,500,000 in the Coal to Solar and Energy Storage
3893	3893	9 Initiative Fund for grants, assuming sufficient
3894	3894	10 qualifying applicants, to support installation of
3895	3895	11 energy storage facilities at the sites of up to 3
3896	3896	12 qualifying electric generating facilities located in
3897	3897	13 the Midcontinent Independent System Operator, Inc.,
3898	3898	14 region in Illinois and the sites of up to 2 qualifying
3899	3899	15 electric generating facilities located in the PJM
3900	3900	16 Interconnection, LLC region in Illinois that meet the
3901	3901	17 criteria set forth in this subparagraph (C). The
3902	3902	18 criteria for receipt of a grant pursuant to this
3903	3903	19 subparagraph (C) are as follows:
3904	3904	20 (1) the electric generating facility at the
3905	3905	21 site has, or had prior to retirement, an electric
3906	3906	22 generating capacity of at least 150 megawatts;
3907	3907	23 (2) the electric generating facility burns (or
3908	3908	24 burned prior to retirement) coal as its primary
3909	3909	25 source of fuel;
3910	3910	26 (3) if the electric generating facility is
3911	3911
3912	3912
3913	3913
3914	3914
3915	3915
3916	3916	SB1442 - 108 - LRB104 11424 BDA 21512 b
3917	3917
3918	3918
3919	3919	SB1442- 109 -LRB104 11424 BDA 21512 b SB1442 - 109 - LRB104 11424 BDA 21512 b
3920	3920	SB1442 - 109 - LRB104 11424 BDA 21512 b
3921	3921	1 retired, it was retired subsequent to January 1,
3922	3922	2 2016;
3923	3923	3 (4) the owner of the electric generating
3924	3924	4 facility has not been selected by the Agency
3925	3925	5 pursuant to this subsection (c-5) of this Section
3926	3926	6 to enter into a contract to sell renewable energy
3927	3927	7 credits to one or more electric utilities from a
3928	3928	8 new renewable energy facility located or to be
3929	3929	9 located at or adjacent to the site at which the
3930	3930	10 electric generating facility is located;
3931	3931	11 (5) the electric generating facility located
3932	3932	12 at the site was at one time owned, in whole or in
3933	3933	13 part, by a public utility as defined in Section
3934	3934	14 3-105 of the Public Utilities Act;
3935	3935	15 (6) the electric generating facility at the
3936	3936	16 site is not owned by (i) an electric cooperative
3937	3937	17 as defined in Section 3-119 of the Public
3938	3938	18 Utilities Act, or (ii) an entity described in
3939	3939	19 subsection (b)(1) of Section 3-105 of the Public
3940	3940	20 Utilities Act, or an association or consortium of
3941	3941	21 or an entity owned by entities described in items
3942	3942	22 (i) or (ii);
3943	3943	23 (7) the proposed energy storage facility at
3944	3944	24 the site will have energy storage capacity of at
3945	3945	25 least 37 megawatts;
3946	3946	26 (8) the owner commits to place the energy
3947	3947
3948	3948
3949	3949
3950	3950
3951	3951
3952	3952	SB1442 - 109 - LRB104 11424 BDA 21512 b
3953	3953
3954	3954
3955	3955	SB1442- 110 -LRB104 11424 BDA 21512 b SB1442 - 110 - LRB104 11424 BDA 21512 b
3956	3956	SB1442 - 110 - LRB104 11424 BDA 21512 b
3957	3957	1 storage facility into commercial operation on
3958	3958	2 either June 1, 2023, June 1, 2024, or June 1, 2025,
3959	3959	3 with such date subject to adjustment as needed due
3960	3960	4 to any delays in completing the grant contracting
3961	3961	5 process, in finalizing interconnection agreements
3962	3962	6 and in installing interconnection facilities, and
3963	3963	7 in obtaining necessary governmental permits and
3964	3964	8 approvals;
3965	3965	9 (9) the owner agrees that the new energy
3966	3966	10 storage facility will be constructed or installed
3967	3967	11 by a qualified entity or entities consistent with
3968	3968	12 the requirements of subsection (g) of Section
3969	3969	13 16-128A of the Public Utilities Act and any rules
3970	3970	14 adopted under that Section;
3971	3971	15 (10) the owner agrees that personnel operating
3972	3972	16 the energy storage facility will have the
3973	3973	17 requisite skills, knowledge, training, experience,
3974	3974	18 and competence, which may be demonstrated by
3975	3975	19 completion or current participation and ultimate
3976	3976	20 completion by employees of an accredited or
3977	3977	21 otherwise recognized apprenticeship program for
3978	3978	22 the employee's particular craft, trade, or skill,
3979	3979	23 including through training and education courses
3980	3980	24 and opportunities offered by the owner to
3981	3981	25 employees of the coal-fueled electric generating
3982	3982	26 facility or by previous employment experience
3983	3983
3984	3984
3985	3985
3986	3986
3987	3987
3988	3988	SB1442 - 110 - LRB104 11424 BDA 21512 b
3989	3989
3990	3990
3991	3991	SB1442- 111 -LRB104 11424 BDA 21512 b SB1442 - 111 - LRB104 11424 BDA 21512 b
3992	3992	SB1442 - 111 - LRB104 11424 BDA 21512 b
3993	3993	1 performing the employee's particular work skill or
3994	3994	2 function;
3995	3995	3 (11) the owner commits that not less than the
3996	3996	4 prevailing wage, as determined pursuant to the
3997	3997	5 Prevailing Wage Act, will be paid to the owner's
3998	3998	6 employees engaged in construction activities
3999	3999	7 associated with the new energy storage facility
4000	4000	8 and to the employees of the owner's contractors
4001	4001	9 engaged in construction activities associated with
4002	4002	10 the new energy storage facility, and that, on or
4003	4003	11 before the commercial operation date of the new
4004	4004	12 energy storage facility, the owner shall file a
4005	4005	13 report with the Department certifying that the
4006	4006	14 requirements of this subparagraph (11) have been
4007	4007	15 met; and
4008	4008	16 (12) the owner commits that if selected to
4009	4009	17 receive a grant, it will negotiate a project labor
4010	4010	18 agreement for the construction of the new energy
4011	4011	19 storage facility that includes provisions
4012	4012	20 requiring the parties to the agreement to work
4013	4013	21 together to establish diversity threshold
4014	4014	22 requirements and to ensure best efforts to meet
4015	4015	23 diversity targets, improve diversity at the
4016	4016	24 applicable job site, create diverse apprenticeship
4017	4017	25 opportunities, and create opportunities to employ
4018	4018	26 former coal-fired power plant workers.
4019	4019
4020	4020
4021	4021
4022	4022
4023	4023
4024	4024	SB1442 - 111 - LRB104 11424 BDA 21512 b
4025	4025
4026	4026
4027	4027	SB1442- 112 -LRB104 11424 BDA 21512 b SB1442 - 112 - LRB104 11424 BDA 21512 b
4028	4028	SB1442 - 112 - LRB104 11424 BDA 21512 b
4029	4029	1 The Department shall accept applications for this
4030	4030	2 grant program until March 31, 2022 and shall announce
4031	4031	3 the award of grants no later than June 1, 2022. The
4032	4032	4 Department shall make the grant payments to a
4033	4033	5 recipient in equal annual amounts for 10 years
4034	4034	6 following the date the energy storage facility is
4035	4035	7 placed into commercial operation. The annual grant
4036	4036	8 payments to a qualifying energy storage facility shall
4037	4037	9 be $110,000 per megawatt of energy storage capacity,
4038	4038	10 with total annual grant payments pursuant to this
4039	4039	11 subparagraph (C) for qualifying energy storage
4040	4040	12 facilities not to exceed $28,050,000 in any year.
4041	4041	13 (D) Grants of funding for energy storage
4042	4042	14 facilities pursuant to subparagraph (C) of this
4043	4043	15 paragraph (10), from the Coal to Solar and Energy
4044	4044	16 Storage Initiative Fund, shall be memorialized in
4045	4045	17 grant contracts between the Department and the
4046	4046	18 recipient. The grant contracts shall specify the date
4047	4047	19 or dates in each year on which the annual grant
4048	4048	20 payments shall be paid.
4049	4049	21 (E) All disbursements from the Coal to Solar and
4050	4050	22 Energy Storage Initiative Fund shall be made only upon
4051	4051	23 warrants of the Comptroller drawn upon the Treasurer
4052	4052	24 as custodian of the Fund upon vouchers signed by the
4053	4053	25 Director of the Department or by the person or persons
4054	4054	26 designated by the Director of the Department for that
4055	4055
4056	4056
4057	4057
4058	4058
4059	4059
4060	4060	SB1442 - 112 - LRB104 11424 BDA 21512 b
4061	4061
4062	4062
4063	4063	SB1442- 113 -LRB104 11424 BDA 21512 b SB1442 - 113 - LRB104 11424 BDA 21512 b
4064	4064	SB1442 - 113 - LRB104 11424 BDA 21512 b
4065	4065	1 purpose. The Comptroller is authorized to draw the
4066	4066	2 warrants upon vouchers so signed. The Treasurer shall
4067	4067	3 accept all written warrants so signed and shall be
4068	4068	4 released from liability for all payments made on those
4069	4069	5 warrants.
4070	4070	6 (11) Diversity, equity, and inclusion plans.
4071	4071	7 (A) Each applicant selected in a procurement event
4072	4072	8 to contract to supply renewable energy credits in
4073	4073	9 accordance with this subsection (c-5) and each owner
4074	4074	10 selected by the Department to receive a grant or
4075	4075	11 grants to support the construction and operation of a
4076	4076	12 new energy storage facility or facilities in
4077	4077	13 accordance with this subsection (c-5) shall, within 60
4078	4078	14 days following the Commission's approval of the
4079	4079	15 applicant to contract to supply renewable energy
4080	4080	16 credits or within 60 days following execution of a
4081	4081	17 grant contract with the Department, as applicable,
4082	4082	18 submit to the Commission a diversity, equity, and
4083	4083	19 inclusion plan setting forth the applicant's or
4084	4084	20 owner's numeric goals for the diversity composition of
4085	4085	21 its supplier entities for the new renewable energy
4086	4086	22 facility or new energy storage facility, as
4087	4087	23 applicable, which shall be referred to for purposes of
4088	4088	24 this paragraph (11) as the project, and the
4089	4089	25 applicant's or owner's action plan and schedule for
4090	4090	26 achieving those goals.
4091	4091
4092	4092
4093	4093
4094	4094
4095	4095
4096	4096	SB1442 - 113 - LRB104 11424 BDA 21512 b
4097	4097
4098	4098
4099	4099	SB1442- 114 -LRB104 11424 BDA 21512 b SB1442 - 114 - LRB104 11424 BDA 21512 b
4100	4100	SB1442 - 114 - LRB104 11424 BDA 21512 b
4101	4101	1 (B) For purposes of this paragraph (11), diversity
4102	4102	2 composition shall be based on the percentage, which
4103	4103	3 shall be a minimum of 25%, of eligible expenditures
4104	4104	4 for contract awards for materials and services (which
4105	4105	5 shall be defined in the plan) to business enterprises
4106	4106	6 owned by minority persons, women, or persons with
4107	4107	7 disabilities as defined in Section 2 of the Business
4108	4108	8 Enterprise for Minorities, Women, and Persons with
4109	4109	9 Disabilities Act, to LGBTQ business enterprises, to
4110	4110	10 veteran-owned business enterprises, and to business
4111	4111	11 enterprises located in environmental justice
4112	4112	12 communities. The diversity composition goals of the
4113	4113	13 plan may include eligible expenditures in areas for
4114	4114	14 vendor or supplier opportunities in addition to
4115	4115	15 development and construction of the project, and may
4116	4116	16 exclude from eligible expenditures materials and
4117	4117	17 services with limited market availability, limited
4118	4118	18 production and availability from suppliers in the
4119	4119	19 United States, such as solar panels and storage
4120	4120	20 batteries, and material and services that are subject
4121	4121	21 to critical energy infrastructure or cybersecurity
4122	4122	22 requirements or restrictions. The plan may provide
4123	4123	23 that the diversity composition goals may be met
4124	4124	24 through Tier 1 Direct or Tier 2 subcontracting
4125	4125	25 expenditures or a combination thereof for the project.
4126	4126	26 (C) The plan shall provide for, but not be limited
4127	4127
4128	4128
4129	4129
4130	4130
4131	4131
4132	4132	SB1442 - 114 - LRB104 11424 BDA 21512 b
4133	4133
4134	4134
4135	4135	SB1442- 115 -LRB104 11424 BDA 21512 b SB1442 - 115 - LRB104 11424 BDA 21512 b
4136	4136	SB1442 - 115 - LRB104 11424 BDA 21512 b
4137	4137	1 to: (i) internal initiatives, including multi-tier
4138	4138	2 initiatives, by the applicant or owner, or by its
4139	4139	3 engineering, procurement and construction contractor
4140	4140	4 if one is used for the project, which for purposes of
4141	4141	5 this paragraph (11) shall be referred to as the EPC
4142	4142	6 contractor, to enable diverse businesses to be
4143	4143	7 considered fairly for selection to provide materials
4144	4144	8 and services; (ii) requirements for the applicant or
4145	4145	9 owner or its EPC contractor to proactively solicit and
4146	4146	10 utilize diverse businesses to provide materials and
4147	4147	11 services; and (iii) requirements for the applicant or
4148	4148	12 owner or its EPC contractor to hire a diverse
4149	4149	13 workforce for the project. The plan shall include a
4150	4150	14 description of the applicant's or owner's diversity
4151	4151	15 recruiting efforts both for the project and for other
4152	4152	16 areas of the applicant's or owner's business
4153	4153	17 operations. The plan shall provide for the imposition
4154	4154	18 of financial penalties on the applicant's or owner's
4155	4155	19 EPC contractor for failure to exercise best efforts to
4156	4156	20 comply with and execute the EPC contractor's diversity
4157	4157	21 obligations under the plan. The plan may provide for
4158	4158	22 the applicant or owner to set aside a portion of the
4159	4159	23 work on the project to serve as an incubation program
4160	4160	24 for qualified businesses, as specified in the plan,
4161	4161	25 owned by minority persons, women, persons with
4162	4162	26 disabilities, LGBTQ persons, and veterans, and
4163	4163
4164	4164
4165	4165
4166	4166
4167	4167
4168	4168	SB1442 - 115 - LRB104 11424 BDA 21512 b
4169	4169
4170	4170
4171	4171	SB1442- 116 -LRB104 11424 BDA 21512 b SB1442 - 116 - LRB104 11424 BDA 21512 b
4172	4172	SB1442 - 116 - LRB104 11424 BDA 21512 b
4173	4173	1 businesses located in environmental justice
4174	4174	2 communities, seeking to enter the renewable energy
4175	4175	3 industry.
4176	4176	4 (D) The applicant or owner may submit a revised or
4177	4177	5 updated plan to the Commission from time to time as
4178	4178	6 circumstances warrant. The applicant or owner shall
4179	4179	7 file annual reports with the Commission detailing the
4180	4180	8 applicant's or owner's progress in implementing its
4181	4181	9 plan and achieving its goals and any modifications the
4182	4182	10 applicant or owner has made to its plan to better
4183	4183	11 achieve its diversity, equity and inclusion goals. The
4184	4184	12 applicant or owner shall file a final report on the
4185	4185	13 fifth June 1 following the commercial operation date
4186	4186	14 of the new renewable energy resource or new energy
4187	4187	15 storage facility, but the applicant or owner shall
4188	4188	16 thereafter continue to be subject to applicable
4189	4189	17 reporting requirements of Section 5-117 of the Public
4190	4190	18 Utilities Act.
4191	4191	19 (c-10) Equity accountability system. It is the purpose of
4192	4192	20 this subsection (c-10) to create an equity accountability
4193	4193	21 system, which includes the minimum equity standards for all
4194	4194	22 renewable energy procurements, the equity category of the
4195	4195	23 Adjustable Block Program, and the equity prioritization for
4196	4196	24 noncompetitive procurements, that is successful in advancing
4197	4197	25 priority access to the clean energy economy for businesses and
4198	4198	26 workers from communities that have been excluded from economic
4199	4199
4200	4200
4201	4201
4202	4202
4203	4203
4204	4204	SB1442 - 116 - LRB104 11424 BDA 21512 b
4205	4205
4206	4206
4207	4207	SB1442- 117 -LRB104 11424 BDA 21512 b SB1442 - 117 - LRB104 11424 BDA 21512 b
4208	4208	SB1442 - 117 - LRB104 11424 BDA 21512 b
4209	4209	1 opportunities in the energy sector, have been subject to
4210	4210	2 disproportionate levels of pollution, and have
4211	4211	3 disproportionately experienced negative public health
4212	4212	4 outcomes. Further, it is the purpose of this subsection to
4213	4213	5 ensure that this equity accountability system is successful in
4214	4214	6 advancing equity across Illinois by providing access to the
4215	4215	7 clean energy economy for businesses and workers from
4216	4216	8 communities that have been historically excluded from economic
4217	4217	9 opportunities in the energy sector, have been subject to
4218	4218	10 disproportionate levels of pollution, and have
4219	4219	11 disproportionately experienced negative public health
4220	4220	12 outcomes.
4221	4221	13 (1) Minimum equity standards. The Agency shall create
4222	4222	14 programs with the purpose of increasing access to and
4223	4223	15 development of equity eligible contractors, who are prime
4224	4224	16 contractors and subcontractors, across all of the programs
4225	4225	17 it manages. All applications for renewable energy credit
4226	4226	18 procurements shall comply with specific minimum equity
4227	4227	19 commitments. Starting in the delivery year immediately
4228	4228	20 following the next long-term renewable resources
4229	4229	21 procurement plan, at least 10% of the project workforce
4230	4230	22 for each entity participating in a procurement program
4231	4231	23 outlined in this subsection (c-10) must be done by equity
4232	4232	24 eligible persons or equity eligible contractors. The
4233	4233	25 Agency shall increase the minimum percentage each delivery
4234	4234	26 year thereafter by increments that ensure a statewide
4235	4235
4236	4236
4237	4237
4238	4238
4239	4239
4240	4240	SB1442 - 117 - LRB104 11424 BDA 21512 b
4241	4241
4242	4242
4243	4243	SB1442- 118 -LRB104 11424 BDA 21512 b SB1442 - 118 - LRB104 11424 BDA 21512 b
4244	4244	SB1442 - 118 - LRB104 11424 BDA 21512 b
4245	4245	1 average of 30% of the project workforce for each entity
4246	4246	2 participating in a procurement program is done by equity
4247	4247	3 eligible persons or equity eligible contractors by 2030.
4248	4248	4 The Agency shall propose a schedule of percentage
4249	4249	5 increases to the minimum equity standards in its draft
4250	4250	6 revised renewable energy resources procurement plan
4251	4251	7 submitted to the Commission for approval pursuant to
4252	4252	8 paragraph (5) of subsection (b) of Section 16-111.5 of the
4253	4253	9 Public Utilities Act. In determining these annual
4254	4254	10 increases, the Agency shall have the discretion to
4255	4255	11 establish different minimum equity standards for different
4256	4256	12 types of procurements and different regions of the State
4257	4257	13 if the Agency finds that doing so will further the
4258	4258	14 purposes of this subsection (c-10). The proposed schedule
4259	4259	15 of annual increases shall be revisited and updated on an
4260	4260	16 annual basis. Revisions shall be developed with
4261	4261	17 stakeholder input, including from equity eligible persons,
4262	4262	18 equity eligible contractors, clean energy industry
4263	4263	19 representatives, and community-based organizations that
4264	4264	20 work with such persons and contractors.
4265	4265	21 (A) At the start of each delivery year, the Agency
4266	4266	22 shall require a compliance plan from each entity
4267	4267	23 participating in a procurement program of subsection
4268	4268	24 (c) of this Section that demonstrates how they will
4269	4269	25 achieve compliance with the minimum equity standard
4270	4270	26 percentage for work completed in that delivery year.
4271	4271
4272	4272
4273	4273
4274	4274
4275	4275
4276	4276	SB1442 - 118 - LRB104 11424 BDA 21512 b
4277	4277
4278	4278
4279	4279	SB1442- 119 -LRB104 11424 BDA 21512 b SB1442 - 119 - LRB104 11424 BDA 21512 b
4280	4280	SB1442 - 119 - LRB104 11424 BDA 21512 b
4281	4281	1 If an entity applies for its approved vendor or
4282	4282	2 designee status between delivery years, the Agency
4283	4283	3 shall require a compliance plan at the time of
4284	4284	4 application.
4285	4285	5 (B) Halfway through each delivery year, the Agency
4286	4286	6 shall require each entity participating in a
4287	4287	7 procurement program to confirm that it will achieve
4288	4288	8 compliance in that delivery year, when applicable. The
4289	4289	9 Agency may offer corrective action plans to entities
4290	4290	10 that are not on track to achieve compliance.
4291	4291	11 (C) At the end of each delivery year, each entity
4292	4292	12 participating and completing work in that delivery
4293	4293	13 year in a procurement program of subsection (c) shall
4294	4294	14 submit a report to the Agency that demonstrates how it
4295	4295	15 achieved compliance with the minimum equity standards
4296	4296	16 percentage for that delivery year.
4297	4297	17 (D) The Agency shall prohibit participation in
4298	4298	18 procurement programs by an approved vendor or
4299	4299	19 designee, as applicable, or entities with which an
4300	4300	20 approved vendor or designee, as applicable, shares a
4301	4301	21 common parent company if an approved vendor or
4302	4302	22 designee, as applicable, failed to meet the minimum
4303	4303	23 equity standards for the prior delivery year. Waivers
4304	4304	24 approved for lack of equity eligible persons or equity
4305	4305	25 eligible contractors in a geographic area of a project
4306	4306	26 shall not count against the approved vendor or
4307	4307
4308	4308
4309	4309
4310	4310
4311	4311
4312	4312	SB1442 - 119 - LRB104 11424 BDA 21512 b
4313	4313
4314	4314
4315	4315	SB1442- 120 -LRB104 11424 BDA 21512 b SB1442 - 120 - LRB104 11424 BDA 21512 b
4316	4316	SB1442 - 120 - LRB104 11424 BDA 21512 b
4317	4317	1 designee. The Agency shall offer a corrective action
4318	4318	2 plan for any such entities to assist them in obtaining
4319	4319	3 compliance and shall allow continued access to
4320	4320	4 procurement programs upon an approved vendor or
4321	4321	5 designee demonstrating compliance.
4322	4322	6 (E) The Agency shall pursue efficiencies achieved
4323	4323	7 by combining with other approved vendor or designee
4324	4324	8 reporting.
4325	4325	9 (2) Equity accountability system within the Adjustable
4326	4326	10 Block program. The equity category described in item (vi)
4327	4327	11 of subparagraph (K) of subsection (c) is only available to
4328	4328	12 applicants that are equity eligible contractors.
4329	4329	13 (3) Equity accountability system within competitive
4330	4330	14 procurements. Through its long-term renewable resources
4331	4331	15 procurement plan, the Agency shall develop requirements
4332	4332	16 for ensuring that competitive procurement processes,
4333	4333	17 including utility-scale solar, utility-scale wind, and
4334	4334	18 brownfield site photovoltaic projects, advance the equity
4335	4335	19 goals of this subsection (c-10). Subject to Commission
4336	4336	20 approval, the Agency shall develop bid application
4337	4337	21 requirements and a bid evaluation methodology for ensuring
4338	4338	22 that utilization of equity eligible contractors, whether
4339	4339	23 as bidders or as participants on project development, is
4340	4340	24 optimized, including requiring that winning or successful
4341	4341	25 applicants for utility-scale projects are or will partner
4342	4342	26 with equity eligible contractors and giving preference to
4343	4343
4344	4344
4345	4345
4346	4346
4347	4347
4348	4348	SB1442 - 120 - LRB104 11424 BDA 21512 b
4349	4349
4350	4350
4351	4351	SB1442- 121 -LRB104 11424 BDA 21512 b SB1442 - 121 - LRB104 11424 BDA 21512 b
4352	4352	SB1442 - 121 - LRB104 11424 BDA 21512 b
4353	4353	1 bids through which a higher portion of contract value
4354	4354	2 flows to equity eligible contractors. To the extent
4355	4355	3 practicable, entities participating in competitive
4356	4356	4 procurements shall also be required to meet all the equity
4357	4357	5 accountability requirements for approved vendors and their
4358	4358	6 designees under this subsection (c-10). In developing
4359	4359	7 these requirements, the Agency shall also consider whether
4360	4360	8 equity goals can be further advanced through additional
4361	4361	9 measures.
4362	4362	10 (4) In the first revision to the long-term renewable
4363	4363	11 energy resources procurement plan and each revision
4364	4364	12 thereafter, the Agency shall include the following:
4365	4365	13 (A) The current status and number of equity
4366	4366	14 eligible contractors listed in the Energy Workforce
4367	4367	15 Equity Database designed in subsection (c-25),
4368	4368	16 including the number of equity eligible contractors
4369	4369	17 with current certifications as issued by the Agency.
4370	4370	18 (B) A mechanism for measuring, tracking, and
4371	4371	19 reporting project workforce at the approved vendor or
4372	4372	20 designee level, as applicable, which shall include a
4373	4373	21 measurement methodology and records to be made
4374	4374	22 available for audit by the Agency or the Program
4375	4375	23 Administrator.
4376	4376	24 (C) A program for approved vendors, designees,
4377	4377	25 eligible persons, and equity eligible contractors to
4378	4378	26 receive trainings, guidance, and other support from
4379	4379
4380	4380
4381	4381
4382	4382
4383	4383
4384	4384	SB1442 - 121 - LRB104 11424 BDA 21512 b
4385	4385
4386	4386
4387	4387	SB1442- 122 -LRB104 11424 BDA 21512 b SB1442 - 122 - LRB104 11424 BDA 21512 b
4388	4388	SB1442 - 122 - LRB104 11424 BDA 21512 b
4389	4389	1 the Agency or its designee regarding the equity
4390	4390	2 category outlined in item (vi) of subparagraph (K) of
4391	4391	3 paragraph (1) of subsection (c) and in meeting the
4392	4392	4 minimum equity standards of this subsection (c-10).
4393	4393	5 (D) A process for certifying equity eligible
4394	4394	6 contractors and equity eligible persons. The
4395	4395	7 certification process shall coordinate with the Energy
4396	4396	8 Workforce Equity Database set forth in subsection
4397	4397	9 (c-25).
4398	4398	10 (E) An application for waiver of the minimum
4399	4399	11 equity standards of this subsection, which the Agency
4400	4400	12 shall have the discretion to grant in rare
4401	4401	13 circumstances. The Agency may grant such a waiver
4402	4402	14 where the applicant provides evidence of significant
4403	4403	15 efforts toward meeting the minimum equity commitment,
4404	4404	16 including: use of the Energy Workforce Equity
4405	4405	17 Database; efforts to hire or contract with entities
4406	4406	18 that hire eligible persons; and efforts to establish
4407	4407	19 contracting relationships with eligible contractors.
4408	4408	20 The Agency shall support applicants in understanding
4409	4409	21 the Energy Workforce Equity Database and other
4410	4410	22 resources for pursuing compliance of the minimum
4411	4411	23 equity standards. Waivers shall be project-specific,
4412	4412	24 unless the Agency deems it necessary to grant a waiver
4413	4413	25 across a portfolio of projects, and in effect for no
4414	4414	26 longer than one year. Any waiver extension or
4415	4415
4416	4416
4417	4417
4418	4418
4419	4419
4420	4420	SB1442 - 122 - LRB104 11424 BDA 21512 b
4421	4421
4422	4422
4423	4423	SB1442- 123 -LRB104 11424 BDA 21512 b SB1442 - 123 - LRB104 11424 BDA 21512 b
4424	4424	SB1442 - 123 - LRB104 11424 BDA 21512 b
4425	4425	1 subsequent waiver request from an applicant shall be
4426	4426	2 subject to the requirements of this Section and shall
4427	4427	3 specify efforts made to reach compliance. When
4428	4428	4 considering whether to grant a waiver, and to what
4429	4429	5 extent, the Agency shall consider the degree to which
4430	4430	6 similarly situated applicants have been able to meet
4431	4431	7 these minimum equity commitments. For repeated waiver
4432	4432	8 requests for specific lack of eligible persons or
4433	4433	9 eligible contractors available, the Agency shall make
4434	4434	10 recommendations to target recruitment to add such
4435	4435	11 eligible persons or eligible contractors to the
4436	4436	12 database.
4437	4437	13 (5) The Agency shall collect information about work on
4438	4438	14 projects or portfolios of projects subject to these
4439	4439	15 minimum equity standards to ensure compliance with this
4440	4440	16 subsection (c-10). Reporting in furtherance of this
4441	4441	17 requirement may be combined with other annual reporting
4442	4442	18 requirements. Such reporting shall include proof of
4443	4443	19 certification of each equity eligible contractor or equity
4444	4444	20 eligible person during the applicable time period.
4445	4445	21 (6) The Agency shall keep confidential all information
4446	4446	22 and communication that provides private or personal
4447	4447	23 information.
4448	4448	24 (7) Modifications to the equity accountability system.
4449	4449	25 As part of the update of the long-term renewable resources
4450	4450	26 procurement plan to be initiated in 2023, or sooner if the
4451	4451
4452	4452
4453	4453
4454	4454
4455	4455
4456	4456	SB1442 - 123 - LRB104 11424 BDA 21512 b
4457	4457
4458	4458
4459	4459	SB1442- 124 -LRB104 11424 BDA 21512 b SB1442 - 124 - LRB104 11424 BDA 21512 b
4460	4460	SB1442 - 124 - LRB104 11424 BDA 21512 b
4461	4461	1 Agency deems necessary, the Agency shall determine the
4462	4462	2 extent to which the equity accountability system described
4463	4463	3 in this subsection (c-10) has advanced the goals of this
4464	4464	4 amendatory Act of the 102nd General Assembly, including
4465	4465	5 through the inclusion of equity eligible persons and
4466	4466	6 equity eligible contractors in renewable energy credit
4467	4467	7 projects. If the Agency finds that the equity
4468	4468	8 accountability system has failed to meet those goals to
4469	4469	9 its fullest potential, the Agency may revise the following
4470	4470	10 criteria for future Agency procurements: (A) the
4471	4471	11 percentage of project workforce, or other appropriate
4472	4472	12 workforce measure, certified as equity eligible persons or
4473	4473	13 equity eligible contractors; (B) definitions for equity
4474	4474	14 investment eligible persons and equity investment eligible
4475	4475	15 community; and (C) such other modifications necessary to
4476	4476	16 advance the goals of this amendatory Act of the 102nd
4477	4477	17 General Assembly effectively. Such revised criteria may
4478	4478	18 also establish distinct equity accountability systems for
4479	4479	19 different types of procurements or different regions of
4480	4480	20 the State if the Agency finds that doing so will further
4481	4481	21 the purposes of such programs. Revisions shall be
4482	4482	22 developed with stakeholder input, including from equity
4483	4483	23 eligible persons, equity eligible contractors, and
4484	4484	24 community-based organizations that work with such persons
4485	4485	25 and contractors.
4486	4486	26 (c-15) Racial discrimination elimination powers and
4487	4487
4488	4488
4489	4489
4490	4490
4491	4491
4492	4492	SB1442 - 124 - LRB104 11424 BDA 21512 b
4493	4493
4494	4494
4495	4495	SB1442- 125 -LRB104 11424 BDA 21512 b SB1442 - 125 - LRB104 11424 BDA 21512 b
4496	4496	SB1442 - 125 - LRB104 11424 BDA 21512 b
4497	4497	1 process.
4498	4498	2 (1) Purpose. It is the purpose of this subsection to
4499	4499	3 empower the Agency and other State actors to remedy racial
4500	4500	4 discrimination in Illinois' clean energy economy as
4501	4501	5 effectively and expediently as possible, including through
4502	4502	6 the use of race-conscious remedies, such as race-conscious
4503	4503	7 contracting and hiring goals, as consistent with State and
4504	4504	8 federal law.
4505	4505	9 (2) Racial disparity and discrimination review
4506	4506	10 process.
4507	4507	11 (A) Within one year after awarding contracts using
4508	4508	12 the equity actions processes established in this
4509	4509	13 Section, the Agency shall publish a report evaluating
4510	4510	14 the effectiveness of the equity actions point criteria
4511	4511	15 of this Section in increasing participation of equity
4512	4512	16 eligible persons and equity eligible contractors. The
4513	4513	17 report shall disaggregate participating workers and
4514	4514	18 contractors by race and ethnicity. The report shall be
4515	4515	19 forwarded to the Governor, the General Assembly, and
4516	4516	20 the Illinois Commerce Commission and be made available
4517	4517	21 to the public.
4518	4518	22 (B) As soon as is practicable thereafter, the
4519	4519	23 Agency, in consultation with the Department of
4520	4520	24 Commerce and Economic Opportunity, Department of
4521	4521	25 Labor, and other agencies that may be relevant, shall
4522	4522	26 commission and publish a disparity and availability
4523	4523
4524	4524
4525	4525
4526	4526
4527	4527
4528	4528	SB1442 - 125 - LRB104 11424 BDA 21512 b
4529	4529
4530	4530
4531	4531	SB1442- 126 -LRB104 11424 BDA 21512 b SB1442 - 126 - LRB104 11424 BDA 21512 b
4532	4532	SB1442 - 126 - LRB104 11424 BDA 21512 b
4533	4533	1 study that measures the presence and impact of
4534	4534	2 discrimination on minority businesses and workers in
4535	4535	3 Illinois' clean energy economy. The Agency may hire
4536	4536	4 consultants and experts to conduct the disparity and
4537	4537	5 availability study, with the retention of those
4538	4538	6 consultants and experts exempt from the requirements
4539	4539	7 of Section 20-10 of the Illinois Procurement Code. The
4540	4540	8 Illinois Power Agency shall forward a copy of its
4541	4541	9 findings and recommendations to the Governor, the
4542	4542	10 General Assembly, and the Illinois Commerce
4543	4543	11 Commission. If the disparity and availability study
4544	4544	12 establishes a strong basis in evidence that there is
4545	4545	13 discrimination in Illinois' clean energy economy, the
4546	4546	14 Agency, Department of Commerce and Economic
4547	4547	15 Opportunity, Department of Labor, Department of
4548	4548	16 Corrections, and other appropriate agencies shall take
4549	4549	17 appropriate remedial actions, including race-conscious
4550	4550	18 remedial actions as consistent with State and federal
4551	4551	19 law, to effectively remedy this discrimination. Such
4552	4552	20 remedies may include modification of the equity
4553	4553	21 accountability system as described in subsection
4554	4554	22 (c-10).
4555	4555	23 (c-20) Program data collection.
4556	4556	24 (1) Purpose. Data collection, data analysis, and
4557	4557	25 reporting are critical to ensure that the benefits of the
4558	4558	26 clean energy economy provided to Illinois residents and
4559	4559
4560	4560
4561	4561
4562	4562
4563	4563
4564	4564	SB1442 - 126 - LRB104 11424 BDA 21512 b
4565	4565
4566	4566
4567	4567	SB1442- 127 -LRB104 11424 BDA 21512 b SB1442 - 127 - LRB104 11424 BDA 21512 b
4568	4568	SB1442 - 127 - LRB104 11424 BDA 21512 b
4569	4569	1 businesses are equitably distributed across the State. The
4570	4570	2 Agency shall collect data from program applicants in order
4571	4571	3 to track and improve equitable distribution of benefits
4572	4572	4 across Illinois communities for all procurements the
4573	4573	5 Agency conducts. The Agency shall use this data to, among
4574	4574	6 other things, measure any potential impact of racial
4575	4575	7 discrimination on the distribution of benefits and provide
4576	4576	8 information necessary to correct any discrimination
4577	4577	9 through methods consistent with State and federal law.
4578	4578	10 (2) Agency collection of program data. The Agency
4579	4579	11 shall collect demographic and geographic data for each
4580	4580	12 entity awarded contracts under any Agency-administered
4581	4581	13 program.
4582	4582	14 (3) Required information to be collected. The Agency
4583	4583	15 shall collect the following information from applicants
4584	4584	16 and program participants where applicable:
4585	4585	17 (A) demographic information, including racial or
4586	4586	18 ethnic identity for real persons employed, contracted,
4587	4587	19 or subcontracted through the program and owners of
4588	4588	20 businesses or entities that apply to receive renewable
4589	4589	21 energy credits from the Agency;
4590	4590	22 (B) geographic location of the residency of real
4591	4591	23 persons employed, contracted, or subcontracted through
4592	4592	24 the program and geographic location of the
4593	4593	25 headquarters of the business or entity that applies to
4594	4594	26 receive renewable energy credits from the Agency; and
4595	4595
4596	4596
4597	4597
4598	4598
4599	4599
4600	4600	SB1442 - 127 - LRB104 11424 BDA 21512 b
4601	4601
4602	4602
4603	4603	SB1442- 128 -LRB104 11424 BDA 21512 b SB1442 - 128 - LRB104 11424 BDA 21512 b
4604	4604	SB1442 - 128 - LRB104 11424 BDA 21512 b
4605	4605	1 (C) any other information the Agency determines is
4606	4606	2 necessary for the purpose of achieving the purpose of
4607	4607	3 this subsection.
4608	4608	4 (4) Publication of collected information. The Agency
4609	4609	5 shall publish, at least annually, information on the
4610	4610	6 demographics of program participants on an aggregate
4611	4611	7 basis.
4612	4612	8 (5) Nothing in this subsection shall be interpreted to
4613	4613	9 limit the authority of the Agency, or other agency or
4614	4614	10 department of the State, to require or collect demographic
4615	4615	11 information from applicants of other State programs.
4616	4616	12 (c-25) Energy Workforce Equity Database.
4617	4617	13 (1) The Agency, in consultation with the Department of
4618	4618	14 Commerce and Economic Opportunity, shall create an Energy
4619	4619	15 Workforce Equity Database, and may contract with a third
4620	4620	16 party to do so ("database program administrator"). If the
4621	4621	17 Department decides to contract with a third party, that
4622	4622	18 third party shall be exempt from the requirements of
4623	4623	19 Section 20-10 of the Illinois Procurement Code. The Energy
4624	4624	20 Workforce Equity Database shall be a searchable database
4625	4625	21 of suppliers, vendors, and subcontractors for clean energy
4626	4626	22 industries that is:
4627	4627	23 (A) publicly accessible;
4628	4628	24 (B) easy for people to find and use;
4629	4629	25 (C) organized by company specialty or field;
4630	4630	26 (D) region-specific; and
4631	4631
4632	4632
4633	4633
4634	4634
4635	4635
4636	4636	SB1442 - 128 - LRB104 11424 BDA 21512 b
4637	4637
4638	4638
4639	4639	SB1442- 129 -LRB104 11424 BDA 21512 b SB1442 - 129 - LRB104 11424 BDA 21512 b
4640	4640	SB1442 - 129 - LRB104 11424 BDA 21512 b
4641	4641	1 (E) populated with information including, but not
4642	4642	2 limited to, contacts for suppliers, vendors, or
4643	4643	3 subcontractors who are minority and women-owned
4644	4644	4 business enterprise certified or who participate or
4645	4645	5 have participated in any of the programs described in
4646	4646	6 this Act.
4647	4647	7 (2) The Agency shall create an easily accessible,
4648	4648	8 public facing online tool using the database information
4649	4649	9 that includes, at a minimum, the following:
4650	4650	10 (A) a map of environmental justice and equity
4651	4651	11 investment eligible communities;
4652	4652	12 (B) job postings and recruiting opportunities;
4653	4653	13 (C) a means by which recruiting clean energy
4654	4654	14 companies can find and interact with current or former
4655	4655	15 participants of clean energy workforce training
4656	4656	16 programs;
4657	4657	17 (D) information on workforce training service
4658	4658	18 providers and training opportunities available to
4659	4659	19 prospective workers;
4660	4660	20 (E) renewable energy company diversity reporting;
4661	4661	21 (F) a list of equity eligible contractors with
4662	4662	22 their contact information, types of work performed,
4663	4663	23 and locations worked in;
4664	4664	24 (G) reporting on outcomes of the programs
4665	4665	25 described in the workforce programs of the Energy
4666	4666	26 Transition Act, including information such as, but not
4667	4667
4668	4668
4669	4669
4670	4670
4671	4671
4672	4672	SB1442 - 129 - LRB104 11424 BDA 21512 b
4673	4673
4674	4674
4675	4675	SB1442- 130 -LRB104 11424 BDA 21512 b SB1442 - 130 - LRB104 11424 BDA 21512 b
4676	4676	SB1442 - 130 - LRB104 11424 BDA 21512 b
4677	4677	1 limited to, retention rate, graduation rate, and
4678	4678	2 placement rates of trainees; and
4679	4679	3 (H) information about the Jobs and Environmental
4680	4680	4 Justice Grant Program, the Clean Energy Jobs and
4681	4681	5 Justice Fund, and other sources of capital.
4682	4682	6 (3) The Agency shall ensure the database is regularly
4683	4683	7 updated to ensure information is current and shall
4684	4684	8 coordinate with the Department of Commerce and Economic
4685	4685	9 Opportunity to ensure that it includes information on
4686	4686	10 individuals and entities that are or have participated in
4687	4687	11 the Clean Jobs Workforce Network Program, Clean Energy
4688	4688	12 Contractor Incubator Program, Returning Residents Clean
4689	4689	13 Jobs Training Program, or Clean Energy Primes Contractor
4690	4690	14 Accelerator Program.
4691	4691	15 (c-30) Enforcement of minimum equity standards. All
4692	4692	16 entities seeking renewable energy credits must submit an
4693	4693	17 annual report to demonstrate compliance with each of the
4694	4694	18 equity commitments required under subsection (c-10). If the
4695	4695	19 Agency concludes the entity has not met or maintained its
4696	4696	20 minimum equity standards required under the applicable
4697	4697	21 subparagraphs under subsection (c-10), the Agency shall deny
4698	4698	22 the entity's ability to participate in procurement programs in
4699	4699	23 subsection (c), including by withholding approved vendor or
4700	4700	24 designee status. The Agency may require the entity to enter
4701	4701	25 into a corrective action plan. An entity that is not
4702	4702	26 recertified for failing to meet required equity actions in
4703	4703
4704	4704
4705	4705
4706	4706
4707	4707
4708	4708	SB1442 - 130 - LRB104 11424 BDA 21512 b
4709	4709
4710	4710
4711	4711	SB1442- 131 -LRB104 11424 BDA 21512 b SB1442 - 131 - LRB104 11424 BDA 21512 b
4712	4712	SB1442 - 131 - LRB104 11424 BDA 21512 b
4713	4713	1 subparagraph (c-10) may reapply once they have a corrective
4714	4714	2 action plan and achieve compliance with the minimum equity
4715	4715	3 standards.
4716	4716	4 (d) Clean coal portfolio standard.
4717	4717	5 (1) The procurement plans shall include electricity
4718	4718	6 generated using clean coal. Each utility shall enter into
4719	4719	7 one or more sourcing agreements with the initial clean
4720	4720	8 coal facility, as provided in paragraph (3) of this
4721	4721	9 subsection (d), covering electricity generated by the
4722	4722	10 initial clean coal facility representing at least 5% of
4723	4723	11 each utility's total supply to serve the load of eligible
4724	4724	12 retail customers in 2015 and each year thereafter, as
4725	4725	13 described in paragraph (3) of this subsection (d), subject
4726	4726	14 to the limits specified in paragraph (2) of this
4727	4727	15 subsection (d). It is the goal of the State that by January
4728	4728	16 1, 2025, 25% of the electricity used in the State shall be
4729	4729	17 generated by cost-effective clean coal facilities. For
4730	4730	18 purposes of this subsection (d), "cost-effective" means
4731	4731	19 that the expenditures pursuant to such sourcing agreements
4732	4732	20 do not cause the limit stated in paragraph (2) of this
4733	4733	21 subsection (d) to be exceeded and do not exceed cost-based
4734	4734	22 benchmarks, which shall be developed to assess all
4735	4735	23 expenditures pursuant to such sourcing agreements covering
4736	4736	24 electricity generated by clean coal facilities, other than
4737	4737	25 the initial clean coal facility, by the procurement
4738	4738	26 administrator, in consultation with the Commission staff,
4739	4739
4740	4740
4741	4741
4742	4742
4743	4743
4744	4744	SB1442 - 131 - LRB104 11424 BDA 21512 b
4745	4745
4746	4746
4747	4747	SB1442- 132 -LRB104 11424 BDA 21512 b SB1442 - 132 - LRB104 11424 BDA 21512 b
4748	4748	SB1442 - 132 - LRB104 11424 BDA 21512 b
4749	4749	1 Agency staff, and the procurement monitor and shall be
4750	4750	2 subject to Commission review and approval.
4751	4751	3 A utility party to a sourcing agreement shall
4752	4752	4 immediately retire any emission credits that it receives
4753	4753	5 in connection with the electricity covered by such
4754	4754	6 agreement.
4755	4755	7 Utilities shall maintain adequate records documenting
4756	4756	8 the purchases under the sourcing agreement to comply with
4757	4757	9 this subsection (d) and shall file an accounting with the
4758	4758	10 load forecast that must be filed with the Agency by July 15
4759	4759	11 of each year, in accordance with subsection (d) of Section
4760	4760	12 16-111.5 of the Public Utilities Act.
4761	4761	13 A utility shall be deemed to have complied with the
4762	4762	14 clean coal portfolio standard specified in this subsection
4763	4763	15 (d) if the utility enters into a sourcing agreement as
4764	4764	16 required by this subsection (d).
4765	4765	17 (2) For purposes of this subsection (d), the required
4766	4766	18 execution of sourcing agreements with the initial clean
4767	4767	19 coal facility for a particular year shall be measured as a
4768	4768	20 percentage of the actual amount of electricity
4769	4769	21 (megawatt-hours) supplied by the electric utility to
4770	4770	22 eligible retail customers in the planning year ending
4771	4771	23 immediately prior to the agreement's execution. For
4772	4772	24 purposes of this subsection (d), the amount paid per
4773	4773	25 kilowatthour means the total amount paid for electric
4774	4774	26 service expressed on a per kilowatthour basis. For
4775	4775
4776	4776
4777	4777
4778	4778
4779	4779
4780	4780	SB1442 - 132 - LRB104 11424 BDA 21512 b
4781	4781
4782	4782
4783	4783	SB1442- 133 -LRB104 11424 BDA 21512 b SB1442 - 133 - LRB104 11424 BDA 21512 b
4784	4784	SB1442 - 133 - LRB104 11424 BDA 21512 b
4785	4785	1 purposes of this subsection (d), the total amount paid for
4786	4786	2 electric service includes without limitation amounts paid
4787	4787	3 for supply, transmission, distribution, surcharges and
4788	4788	4 add-on taxes.
4789	4789	5 Notwithstanding the requirements of this subsection
4790	4790	6 (d), the total amount paid under sourcing agreements with
4791	4791	7 clean coal facilities pursuant to the procurement plan for
4792	4792	8 any given year shall be reduced by an amount necessary to
4793	4793	9 limit the annual estimated average net increase due to the
4794	4794	10 costs of these resources included in the amounts paid by
4795	4795	11 eligible retail customers in connection with electric
4796	4796	12 service to:
4797	4797	13 (A) in 2010, no more than 0.5% of the amount paid
4798	4798	14 per kilowatthour by those customers during the year
4799	4799	15 ending May 31, 2009;
4800	4800	16 (B) in 2011, the greater of an additional 0.5% of
4801	4801	17 the amount paid per kilowatthour by those customers
4802	4802	18 during the year ending May 31, 2010 or 1% of the amount
4803	4803	19 paid per kilowatthour by those customers during the
4804	4804	20 year ending May 31, 2009;
4805	4805	21 (C) in 2012, the greater of an additional 0.5% of
4806	4806	22 the amount paid per kilowatthour by those customers
4807	4807	23 during the year ending May 31, 2011 or 1.5% of the
4808	4808	24 amount paid per kilowatthour by those customers during
4809	4809	25 the year ending May 31, 2009;
4810	4810	26 (D) in 2013, the greater of an additional 0.5% of
4811	4811
4812	4812
4813	4813
4814	4814
4815	4815
4816	4816	SB1442 - 133 - LRB104 11424 BDA 21512 b
4817	4817
4818	4818
4819	4819	SB1442- 134 -LRB104 11424 BDA 21512 b SB1442 - 134 - LRB104 11424 BDA 21512 b
4820	4820	SB1442 - 134 - LRB104 11424 BDA 21512 b
4821	4821	1 the amount paid per kilowatthour by those customers
4822	4822	2 during the year ending May 31, 2012 or 2% of the amount
4823	4823	3 paid per kilowatthour by those customers during the
4824	4824	4 year ending May 31, 2009; and
4825	4825	5 (E) thereafter, the total amount paid under
4826	4826	6 sourcing agreements with clean coal facilities
4827	4827	7 pursuant to the procurement plan for any single year
4828	4828	8 shall be reduced by an amount necessary to limit the
4829	4829	9 estimated average net increase due to the cost of
4830	4830	10 these resources included in the amounts paid by
4831	4831	11 eligible retail customers in connection with electric
4832	4832	12 service to no more than the greater of (i) 2.015% of
4833	4833	13 the amount paid per kilowatthour by those customers
4834	4834	14 during the year ending May 31, 2009 or (ii) the
4835	4835	15 incremental amount per kilowatthour paid for these
4836	4836	16 resources in 2013. These requirements may be altered
4837	4837	17 only as provided by statute.
4838	4838	18 No later than June 30, 2015, the Commission shall
4839	4839	19 review the limitation on the total amount paid under
4840	4840	20 sourcing agreements, if any, with clean coal facilities
4841	4841	21 pursuant to this subsection (d) and report to the General
4842	4842	22 Assembly its findings as to whether that limitation unduly
4843	4843	23 constrains the amount of electricity generated by
4844	4844	24 cost-effective clean coal facilities that is covered by
4845	4845	25 sourcing agreements.
4846	4846	26 (3) Initial clean coal facility. In order to promote
4847	4847
4848	4848
4849	4849
4850	4850
4851	4851
4852	4852	SB1442 - 134 - LRB104 11424 BDA 21512 b
4853	4853
4854	4854
4855	4855	SB1442- 135 -LRB104 11424 BDA 21512 b SB1442 - 135 - LRB104 11424 BDA 21512 b
4856	4856	SB1442 - 135 - LRB104 11424 BDA 21512 b
4857	4857	1 development of clean coal facilities in Illinois, each
4858	4858	2 electric utility subject to this Section shall execute a
4859	4859	3 sourcing agreement to source electricity from a proposed
4860	4860	4 clean coal facility in Illinois (the "initial clean coal
4861	4861	5 facility") that will have a nameplate capacity of at least
4862	4862	6 500 MW when commercial operation commences, that has a
4863	4863	7 final Clean Air Act permit on June 1, 2009 (the effective
4864	4864	8 date of Public Act 95-1027), and that will meet the
4865	4865	9 definition of clean coal facility in Section 1-10 of this
4866	4866	10 Act when commercial operation commences. The sourcing
4867	4867	11 agreements with this initial clean coal facility shall be
4868	4868	12 subject to both approval of the initial clean coal
4869	4869	13 facility by the General Assembly and satisfaction of the
4870	4870	14 requirements of paragraph (4) of this subsection (d) and
4871	4871	15 shall be executed within 90 days after any such approval
4872	4872	16 by the General Assembly. The Agency and the Commission
4873	4873	17 shall have authority to inspect all books and records
4874	4874	18 associated with the initial clean coal facility during the
4875	4875	19 term of such a sourcing agreement. A utility's sourcing
4876	4876	20 agreement for electricity produced by the initial clean
4877	4877	21 coal facility shall include:
4878	4878	22 (A) a formula contractual price (the "contract
4879	4879	23 price") approved pursuant to paragraph (4) of this
4880	4880	24 subsection (d), which shall:
4881	4881	25 (i) be determined using a cost of service
4882	4882	26 methodology employing either a level or deferred
4883	4883
4884	4884
4885	4885
4886	4886
4887	4887
4888	4888	SB1442 - 135 - LRB104 11424 BDA 21512 b
4889	4889
4890	4890
4891	4891	SB1442- 136 -LRB104 11424 BDA 21512 b SB1442 - 136 - LRB104 11424 BDA 21512 b
4892	4892	SB1442 - 136 - LRB104 11424 BDA 21512 b
4893	4893	1 capital recovery component, based on a capital
4894	4894	2 structure consisting of 45% equity and 55% debt,
4895	4895	3 and a return on equity as may be approved by the
4896	4896	4 Federal Energy Regulatory Commission, which in any
4897	4897	5 case may not exceed the lower of 11.5% or the rate
4898	4898	6 of return approved by the General Assembly
4899	4899	7 pursuant to paragraph (4) of this subsection (d);
4900	4900	8 and
4901	4901	9 (ii) provide that all miscellaneous net
4902	4902	10 revenue, including but not limited to net revenue
4903	4903	11 from the sale of emission allowances, if any,
4904	4904	12 substitute natural gas, if any, grants or other
4905	4905	13 support provided by the State of Illinois or the
4906	4906	14 United States Government, firm transmission
4907	4907	15 rights, if any, by-products produced by the
4908	4908	16 facility, energy or capacity derived from the
4909	4909	17 facility and not covered by a sourcing agreement
4910	4910	18 pursuant to paragraph (3) of this subsection (d)
4911	4911	19 or item (5) of subsection (d) of Section 16-115 of
4912	4912	20 the Public Utilities Act, whether generated from
4913	4913	21 the synthesis gas derived from coal, from SNG, or
4914	4914	22 from natural gas, shall be credited against the
4915	4915	23 revenue requirement for this initial clean coal
4916	4916	24 facility;
4917	4917	25 (B) power purchase provisions, which shall:
4918	4918	26 (i) provide that the utility party to such
4919	4919
4920	4920
4921	4921
4922	4922
4923	4923
4924	4924	SB1442 - 136 - LRB104 11424 BDA 21512 b
4925	4925
4926	4926
4927	4927	SB1442- 137 -LRB104 11424 BDA 21512 b SB1442 - 137 - LRB104 11424 BDA 21512 b
4928	4928	SB1442 - 137 - LRB104 11424 BDA 21512 b
4929	4929	1 sourcing agreement shall pay the contract price
4930	4930	2 for electricity delivered under such sourcing
4931	4931	3 agreement;
4932	4932	4 (ii) require delivery of electricity to the
4933	4933	5 regional transmission organization market of the
4934	4934	6 utility that is party to such sourcing agreement;
4935	4935	7 (iii) require the utility party to such
4936	4936	8 sourcing agreement to buy from the initial clean
4937	4937	9 coal facility in each hour an amount of energy
4938	4938	10 equal to all clean coal energy made available from
4939	4939	11 the initial clean coal facility during such hour
4940	4940	12 times a fraction, the numerator of which is such
4941	4941	13 utility's retail market sales of electricity
4942	4942	14 (expressed in kilowatthours sold) in the State
4943	4943	15 during the prior calendar month and the
4944	4944	16 denominator of which is the total retail market
4945	4945	17 sales of electricity (expressed in kilowatthours
4946	4946	18 sold) in the State by utilities during such prior
4947	4947	19 month and the sales of electricity (expressed in
4948	4948	20 kilowatthours sold) in the State by alternative
4949	4949	21 retail electric suppliers during such prior month
4950	4950	22 that are subject to the requirements of this
4951	4951	23 subsection (d) and paragraph (5) of subsection (d)
4952	4952	24 of Section 16-115 of the Public Utilities Act,
4953	4953	25 provided that the amount purchased by the utility
4954	4954	26 in any year will be limited by paragraph (2) of
4955	4955
4956	4956
4957	4957
4958	4958
4959	4959
4960	4960	SB1442 - 137 - LRB104 11424 BDA 21512 b
4961	4961
4962	4962
4963	4963	SB1442- 138 -LRB104 11424 BDA 21512 b SB1442 - 138 - LRB104 11424 BDA 21512 b
4964	4964	SB1442 - 138 - LRB104 11424 BDA 21512 b
4965	4965	1 this subsection (d); and
4966	4966	2 (iv) be considered pre-existing contracts in
4967	4967	3 such utility's procurement plans for eligible
4968	4968	4 retail customers;
4969	4969	5 (C) contract for differences provisions, which
4970	4970	6 shall:
4971	4971	7 (i) require the utility party to such sourcing
4972	4972	8 agreement to contract with the initial clean coal
4973	4973	9 facility in each hour with respect to an amount of
4974	4974	10 energy equal to all clean coal energy made
4975	4975	11 available from the initial clean coal facility
4976	4976	12 during such hour times a fraction, the numerator
4977	4977	13 of which is such utility's retail market sales of
4978	4978	14 electricity (expressed in kilowatthours sold) in
4979	4979	15 the utility's service territory in the State
4980	4980	16 during the prior calendar month and the
4981	4981	17 denominator of which is the total retail market
4982	4982	18 sales of electricity (expressed in kilowatthours
4983	4983	19 sold) in the State by utilities during such prior
4984	4984	20 month and the sales of electricity (expressed in
4985	4985	21 kilowatthours sold) in the State by alternative
4986	4986	22 retail electric suppliers during such prior month
4987	4987	23 that are subject to the requirements of this
4988	4988	24 subsection (d) and paragraph (5) of subsection (d)
4989	4989	25 of Section 16-115 of the Public Utilities Act,
4990	4990	26 provided that the amount paid by the utility in
4991	4991
4992	4992
4993	4993
4994	4994
4995	4995
4996	4996	SB1442 - 138 - LRB104 11424 BDA 21512 b
4997	4997
4998	4998
4999	4999	SB1442- 139 -LRB104 11424 BDA 21512 b SB1442 - 139 - LRB104 11424 BDA 21512 b
5000	5000	SB1442 - 139 - LRB104 11424 BDA 21512 b
5001	5001	1 any year will be limited by paragraph (2) of this
5002	5002	2 subsection (d);
5003	5003	3 (ii) provide that the utility's payment
5004	5004	4 obligation in respect of the quantity of
5005	5005	5 electricity determined pursuant to the preceding
5006	5006	6 clause (i) shall be limited to an amount equal to
5007	5007	7 (1) the difference between the contract price
5008	5008	8 determined pursuant to subparagraph (A) of
5009	5009	9 paragraph (3) of this subsection (d) and the
5010	5010	10 day-ahead price for electricity delivered to the
5011	5011	11 regional transmission organization market of the
5012	5012	12 utility that is party to such sourcing agreement
5013	5013	13 (or any successor delivery point at which such
5014	5014	14 utility's supply obligations are financially
5015	5015	15 settled on an hourly basis) (the "reference
5016	5016	16 price") on the day preceding the day on which the
5017	5017	17 electricity is delivered to the initial clean coal
5018	5018	18 facility busbar, multiplied by (2) the quantity of
5019	5019	19 electricity determined pursuant to the preceding
5020	5020	20 clause (i); and
5021	5021	21 (iii) not require the utility to take physical
5022	5022	22 delivery of the electricity produced by the
5023	5023	23 facility;
5024	5024	24 (D) general provisions, which shall:
5025	5025	25 (i) specify a term of no more than 30 years,
5026	5026	26 commencing on the commercial operation date of the
5027	5027
5028	5028
5029	5029
5030	5030
5031	5031
5032	5032	SB1442 - 139 - LRB104 11424 BDA 21512 b
5033	5033
5034	5034
5035	5035	SB1442- 140 -LRB104 11424 BDA 21512 b SB1442 - 140 - LRB104 11424 BDA 21512 b
5036	5036	SB1442 - 140 - LRB104 11424 BDA 21512 b
5037	5037	1 facility;
5038	5038	2 (ii) provide that utilities shall maintain
5039	5039	3 adequate records documenting purchases under the
5040	5040	4 sourcing agreements entered into to comply with
5041	5041	5 this subsection (d) and shall file an accounting
5042	5042	6 with the load forecast that must be filed with the
5043	5043	7 Agency by July 15 of each year, in accordance with
5044	5044	8 subsection (d) of Section 16-111.5 of the Public
5045	5045	9 Utilities Act;
5046	5046	10 (iii) provide that all costs associated with
5047	5047	11 the initial clean coal facility will be
5048	5048	12 periodically reported to the Federal Energy
5049	5049	13 Regulatory Commission and to purchasers in
5050	5050	14 accordance with applicable laws governing
5051	5051	15 cost-based wholesale power contracts;
5052	5052	16 (iv) permit the Illinois Power Agency to
5053	5053	17 assume ownership of the initial clean coal
5054	5054	18 facility, without monetary consideration and
5055	5055	19 otherwise on reasonable terms acceptable to the
5056	5056	20 Agency, if the Agency so requests no less than 3
5057	5057	21 years prior to the end of the stated contract
5058	5058	22 term;
5059	5059	23 (v) require the owner of the initial clean
5060	5060	24 coal facility to provide documentation to the
5061	5061	25 Commission each year, starting in the facility's
5062	5062	26 first year of commercial operation, accurately
5063	5063
5064	5064
5065	5065
5066	5066
5067	5067
5068	5068	SB1442 - 140 - LRB104 11424 BDA 21512 b
5069	5069
5070	5070
5071	5071	SB1442- 141 -LRB104 11424 BDA 21512 b SB1442 - 141 - LRB104 11424 BDA 21512 b
5072	5072	SB1442 - 141 - LRB104 11424 BDA 21512 b
5073	5073	1 reporting the quantity of carbon emissions from
5074	5074	2 the facility that have been captured and
5075	5075	3 sequestered and report any quantities of carbon
5076	5076	4 released from the site or sites at which carbon
5077	5077	5 emissions were sequestered in prior years, based
5078	5078	6 on continuous monitoring of such sites. If, in any
5079	5079	7 year after the first year of commercial operation,
5080	5080	8 the owner of the facility fails to demonstrate
5081	5081	9 that the initial clean coal facility captured and
5082	5082	10 sequestered at least 50% of the total carbon
5083	5083	11 emissions that the facility would otherwise emit
5084	5084	12 or that sequestration of emissions from prior
5085	5085	13 years has failed, resulting in the release of
5086	5086	14 carbon dioxide into the atmosphere, the owner of
5087	5087	15 the facility must offset excess emissions. Any
5088	5088	16 such carbon offsets must be permanent, additional,
5089	5089	17 verifiable, real, located within the State of
5090	5090	18 Illinois, and legally and practicably enforceable.
5091	5091	19 The cost of such offsets for the facility that are
5092	5092	20 not recoverable shall not exceed $15 million in
5093	5093	21 any given year. No costs of any such purchases of
5094	5094	22 carbon offsets may be recovered from a utility or
5095	5095	23 its customers. All carbon offsets purchased for
5096	5096	24 this purpose and any carbon emission credits
5097	5097	25 associated with sequestration of carbon from the
5098	5098	26 facility must be permanently retired. The initial
5099	5099
5100	5100
5101	5101
5102	5102
5103	5103
5104	5104	SB1442 - 141 - LRB104 11424 BDA 21512 b
5105	5105
5106	5106
5107	5107	SB1442- 142 -LRB104 11424 BDA 21512 b SB1442 - 142 - LRB104 11424 BDA 21512 b
5108	5108	SB1442 - 142 - LRB104 11424 BDA 21512 b
5109	5109	1 clean coal facility shall not forfeit its
5110	5110	2 designation as a clean coal facility if the
5111	5111	3 facility fails to fully comply with the applicable
5112	5112	4 carbon sequestration requirements in any given
5113	5113	5 year, provided the requisite offsets are
5114	5114	6 purchased. However, the Attorney General, on
5115	5115	7 behalf of the People of the State of Illinois, may
5116	5116	8 specifically enforce the facility's sequestration
5117	5117	9 requirement and the other terms of this contract
5118	5118	10 provision. Compliance with the sequestration
5119	5119	11 requirements and offset purchase requirements
5120	5120	12 specified in paragraph (3) of this subsection (d)
5121	5121	13 shall be reviewed annually by an independent
5122	5122	14 expert retained by the owner of the initial clean
5123	5123	15 coal facility, with the advance written approval
5124	5124	16 of the Attorney General. The Commission may, in
5125	5125	17 the course of the review specified in item (vii),
5126	5126	18 reduce the allowable return on equity for the
5127	5127	19 facility if the facility willfully fails to comply
5128	5128	20 with the carbon capture and sequestration
5129	5129	21 requirements set forth in this item (v);
5130	5130	22 (vi) include limits on, and accordingly
5131	5131	23 provide for modification of, the amount the
5132	5132	24 utility is required to source under the sourcing
5133	5133	25 agreement consistent with paragraph (2) of this
5134	5134	26 subsection (d);
5135	5135
5136	5136
5137	5137
5138	5138
5139	5139
5140	5140	SB1442 - 142 - LRB104 11424 BDA 21512 b
5141	5141
5142	5142
5143	5143	SB1442- 143 -LRB104 11424 BDA 21512 b SB1442 - 143 - LRB104 11424 BDA 21512 b
5144	5144	SB1442 - 143 - LRB104 11424 BDA 21512 b
5145	5145	1 (vii) require Commission review: (1) to
5146	5146	2 determine the justness, reasonableness, and
5147	5147	3 prudence of the inputs to the formula referenced
5148	5148	4 in subparagraphs (A)(i) through (A)(iii) of
5149	5149	5 paragraph (3) of this subsection (d), prior to an
5150	5150	6 adjustment in those inputs including, without
5151	5151	7 limitation, the capital structure and return on
5152	5152	8 equity, fuel costs, and other operations and
5153	5153	9 maintenance costs and (2) to approve the costs to
5154	5154	10 be passed through to customers under the sourcing
5155	5155	11 agreement by which the utility satisfies its
5156	5156	12 statutory obligations. Commission review shall
5157	5157	13 occur no less than every 3 years, regardless of
5158	5158	14 whether any adjustments have been proposed, and
5159	5159	15 shall be completed within 9 months;
5160	5160	16 (viii) limit the utility's obligation to such
5161	5161	17 amount as the utility is allowed to recover
5162	5162	18 through tariffs filed with the Commission,
5163	5163	19 provided that neither the clean coal facility nor
5164	5164	20 the utility waives any right to assert federal
5165	5165	21 pre-emption or any other argument in response to a
5166	5166	22 purported disallowance of recovery costs;
5167	5167	23 (ix) limit the utility's or alternative retail
5168	5168	24 electric supplier's obligation to incur any
5169	5169	25 liability until such time as the facility is in
5170	5170	26 commercial operation and generating power and
5171	5171
5172	5172
5173	5173
5174	5174
5175	5175
5176	5176	SB1442 - 143 - LRB104 11424 BDA 21512 b
5177	5177
5178	5178
5179	5179	SB1442- 144 -LRB104 11424 BDA 21512 b SB1442 - 144 - LRB104 11424 BDA 21512 b
5180	5180	SB1442 - 144 - LRB104 11424 BDA 21512 b
5181	5181	1 energy and such power and energy is being
5182	5182	2 delivered to the facility busbar;
5183	5183	3 (x) provide that the owner or owners of the
5184	5184	4 initial clean coal facility, which is the
5185	5185	5 counterparty to such sourcing agreement, shall
5186	5186	6 have the right from time to time to elect whether
5187	5187	7 the obligations of the utility party thereto shall
5188	5188	8 be governed by the power purchase provisions or
5189	5189	9 the contract for differences provisions;
5190	5190	10 (xi) append documentation showing that the
5191	5191	11 formula rate and contract, insofar as they relate
5192	5192	12 to the power purchase provisions, have been
5193	5193	13 approved by the Federal Energy Regulatory
5194	5194	14 Commission pursuant to Section 205 of the Federal
5195	5195	15 Power Act;
5196	5196	16 (xii) provide that any changes to the terms of
5197	5197	17 the contract, insofar as such changes relate to
5198	5198	18 the power purchase provisions, are subject to
5199	5199	19 review under the public interest standard applied
5200	5200	20 by the Federal Energy Regulatory Commission
5201	5201	21 pursuant to Sections 205 and 206 of the Federal
5202	5202	22 Power Act; and
5203	5203	23 (xiii) conform with customary lender
5204	5204	24 requirements in power purchase agreements used as
5205	5205	25 the basis for financing non-utility generators.
5206	5206	26 (4) Effective date of sourcing agreements with the
5207	5207
5208	5208
5209	5209
5210	5210
5211	5211
5212	5212	SB1442 - 144 - LRB104 11424 BDA 21512 b
5213	5213
5214	5214
5215	5215	SB1442- 145 -LRB104 11424 BDA 21512 b SB1442 - 145 - LRB104 11424 BDA 21512 b
5216	5216	SB1442 - 145 - LRB104 11424 BDA 21512 b
5217	5217	1 initial clean coal facility. Any proposed sourcing
5218	5218	2 agreement with the initial clean coal facility shall not
5219	5219	3 become effective unless the following reports are prepared
5220	5220	4 and submitted and authorizations and approvals obtained:
5221	5221	5 (i) Facility cost report. The owner of the initial
5222	5222	6 clean coal facility shall submit to the Commission,
5223	5223	7 the Agency, and the General Assembly a front-end
5224	5224	8 engineering and design study, a facility cost report,
5225	5225	9 method of financing (including but not limited to
5226	5226	10 structure and associated costs), and an operating and
5227	5227	11 maintenance cost quote for the facility (collectively
5228	5228	12 "facility cost report"), which shall be prepared in
5229	5229	13 accordance with the requirements of this paragraph (4)
5230	5230	14 of subsection (d) of this Section, and shall provide
5231	5231	15 the Commission and the Agency access to the work
5232	5232	16 papers, relied upon documents, and any other backup
5233	5233	17 documentation related to the facility cost report.
5234	5234	18 (ii) Commission report. Within 6 months following
5235	5235	19 receipt of the facility cost report, the Commission,
5236	5236	20 in consultation with the Agency, shall submit a report
5237	5237	21 to the General Assembly setting forth its analysis of
5238	5238	22 the facility cost report. Such report shall include,
5239	5239	23 but not be limited to, a comparison of the costs
5240	5240	24 associated with electricity generated by the initial
5241	5241	25 clean coal facility to the costs associated with
5242	5242	26 electricity generated by other types of generation
5243	5243
5244	5244
5245	5245
5246	5246
5247	5247
5248	5248	SB1442 - 145 - LRB104 11424 BDA 21512 b
5249	5249
5250	5250
5251	5251	SB1442- 146 -LRB104 11424 BDA 21512 b SB1442 - 146 - LRB104 11424 BDA 21512 b
5252	5252	SB1442 - 146 - LRB104 11424 BDA 21512 b
5253	5253	1 facilities, an analysis of the rate impacts on
5254	5254	2 residential and small business customers over the life
5255	5255	3 of the sourcing agreements, and an analysis of the
5256	5256	4 likelihood that the initial clean coal facility will
5257	5257	5 commence commercial operation by and be delivering
5258	5258	6 power to the facility's busbar by 2016. To assist in
5259	5259	7 the preparation of its report, the Commission, in
5260	5260	8 consultation with the Agency, may hire one or more
5261	5261	9 experts or consultants, the costs of which shall be
5262	5262	10 paid for by the owner of the initial clean coal
5263	5263	11 facility. The Commission and Agency may begin the
5264	5264	12 process of selecting such experts or consultants prior
5265	5265	13 to receipt of the facility cost report.
5266	5266	14 (iii) General Assembly approval. The proposed
5267	5267	15 sourcing agreements shall not take effect unless,
5268	5268	16 based on the facility cost report and the Commission's
5269	5269	17 report, the General Assembly enacts authorizing
5270	5270	18 legislation approving (A) the projected price, stated
5271	5271	19 in cents per kilowatthour, to be charged for
5272	5272	20 electricity generated by the initial clean coal
5273	5273	21 facility, (B) the projected impact on residential and
5274	5274	22 small business customers' bills over the life of the
5275	5275	23 sourcing agreements, and (C) the maximum allowable
5276	5276	24 return on equity for the project; and
5277	5277	25 (iv) Commission review. If the General Assembly
5278	5278	26 enacts authorizing legislation pursuant to
5279	5279
5280	5280
5281	5281
5282	5282
5283	5283
5284	5284	SB1442 - 146 - LRB104 11424 BDA 21512 b
5285	5285
5286	5286
5287	5287	SB1442- 147 -LRB104 11424 BDA 21512 b SB1442 - 147 - LRB104 11424 BDA 21512 b
5288	5288	SB1442 - 147 - LRB104 11424 BDA 21512 b
5289	5289	1 subparagraph (iii) approving a sourcing agreement, the
5290	5290	2 Commission shall, within 90 days of such enactment,
5291	5291	3 complete a review of such sourcing agreement. During
5292	5292	4 such time period, the Commission shall implement any
5293	5293	5 directive of the General Assembly, resolve any
5294	5294	6 disputes between the parties to the sourcing agreement
5295	5295	7 concerning the terms of such agreement, approve the
5296	5296	8 form of such agreement, and issue an order finding
5297	5297	9 that the sourcing agreement is prudent and reasonable.
5298	5298	10 The facility cost report shall be prepared as follows:
5299	5299	11 (A) The facility cost report shall be prepared by
5300	5300	12 duly licensed engineering and construction firms
5301	5301	13 detailing the estimated capital costs payable to one
5302	5302	14 or more contractors or suppliers for the engineering,
5303	5303	15 procurement and construction of the components
5304	5304	16 comprising the initial clean coal facility and the
5305	5305	17 estimated costs of operation and maintenance of the
5306	5306	18 facility. The facility cost report shall include:
5307	5307	19 (i) an estimate of the capital cost of the
5308	5308	20 core plant based on one or more front end
5309	5309	21 engineering and design studies for the
5310	5310	22 gasification island and related facilities. The
5311	5311	23 core plant shall include all civil, structural,
5312	5312	24 mechanical, electrical, control, and safety
5313	5313	25 systems.
5314	5314	26 (ii) an estimate of the capital cost of the
5315	5315
5316	5316
5317	5317
5318	5318
5319	5319
5320	5320	SB1442 - 147 - LRB104 11424 BDA 21512 b
5321	5321
5322	5322
5323	5323	SB1442- 148 -LRB104 11424 BDA 21512 b SB1442 - 148 - LRB104 11424 BDA 21512 b
5324	5324	SB1442 - 148 - LRB104 11424 BDA 21512 b
5325	5325	1 balance of the plant, including any capital costs
5326	5326	2 associated with sequestration of carbon dioxide
5327	5327	3 emissions and all interconnects and interfaces
5328	5328	4 required to operate the facility, such as
5329	5329	5 transmission of electricity, construction or
5330	5330	6 backfeed power supply, pipelines to transport
5331	5331	7 substitute natural gas or carbon dioxide, potable
5332	5332	8 water supply, natural gas supply, water supply,
5333	5333	9 water discharge, landfill, access roads, and coal
5334	5334	10 delivery.
5335	5335	11 The quoted construction costs shall be expressed
5336	5336	12 in nominal dollars as of the date that the quote is
5337	5337	13 prepared and shall include capitalized financing costs
5338	5338	14 during construction, taxes, insurance, and other
5339	5339	15 owner's costs, and an assumed escalation in materials
5340	5340	16 and labor beyond the date as of which the construction
5341	5341	17 cost quote is expressed.
5342	5342	18 (B) The front end engineering and design study for
5343	5343	19 the gasification island and the cost study for the
5344	5344	20 balance of plant shall include sufficient design work
5345	5345	21 to permit quantification of major categories of
5346	5346	22 materials, commodities and labor hours, and receipt of
5347	5347	23 quotes from vendors of major equipment required to
5348	5348	24 construct and operate the clean coal facility.
5349	5349	25 (C) The facility cost report shall also include an
5350	5350	26 operating and maintenance cost quote that will provide
5351	5351
5352	5352
5353	5353
5354	5354
5355	5355
5356	5356	SB1442 - 148 - LRB104 11424 BDA 21512 b
5357	5357
5358	5358
5359	5359	SB1442- 149 -LRB104 11424 BDA 21512 b SB1442 - 149 - LRB104 11424 BDA 21512 b
5360	5360	SB1442 - 149 - LRB104 11424 BDA 21512 b
5361	5361	1 the estimated cost of delivered fuel, personnel,
5362	5362	2 maintenance contracts, chemicals, catalysts,
5363	5363	3 consumables, spares, and other fixed and variable
5364	5364	4 operations and maintenance costs. The delivered fuel
5365	5365	5 cost estimate will be provided by a recognized third
5366	5366	6 party expert or experts in the fuel and transportation
5367	5367	7 industries. The balance of the operating and
5368	5368	8 maintenance cost quote, excluding delivered fuel
5369	5369	9 costs, will be developed based on the inputs provided
5370	5370	10 by duly licensed engineering and construction firms
5371	5371	11 performing the construction cost quote, potential
5372	5372	12 vendors under long-term service agreements and plant
5373	5373	13 operating agreements, or recognized third party plant
5374	5374	14 operator or operators.
5375	5375	15 The operating and maintenance cost quote
5376	5376	16 (including the cost of the front end engineering and
5377	5377	17 design study) shall be expressed in nominal dollars as
5378	5378	18 of the date that the quote is prepared and shall
5379	5379	19 include taxes, insurance, and other owner's costs, and
5380	5380	20 an assumed escalation in materials and labor beyond
5381	5381	21 the date as of which the operating and maintenance
5382	5382	22 cost quote is expressed.
5383	5383	23 (D) The facility cost report shall also include an
5384	5384	24 analysis of the initial clean coal facility's ability
5385	5385	25 to deliver power and energy into the applicable
5386	5386	26 regional transmission organization markets and an
5387	5387
5388	5388
5389	5389
5390	5390
5391	5391
5392	5392	SB1442 - 149 - LRB104 11424 BDA 21512 b
5393	5393
5394	5394
5395	5395	SB1442- 150 -LRB104 11424 BDA 21512 b SB1442 - 150 - LRB104 11424 BDA 21512 b
5396	5396	SB1442 - 150 - LRB104 11424 BDA 21512 b
5397	5397	1 analysis of the expected capacity factor for the
5398	5398	2 initial clean coal facility.
5399	5399	3 (E) Amounts paid to third parties unrelated to the
5400	5400	4 owner or owners of the initial clean coal facility to
5401	5401	5 prepare the core plant construction cost quote,
5402	5402	6 including the front end engineering and design study,
5403	5403	7 and the operating and maintenance cost quote will be
5404	5404	8 reimbursed through Coal Development Bonds.
5405	5405	9 (5) Re-powering and retrofitting coal-fired power
5406	5406	10 plants previously owned by Illinois utilities to qualify
5407	5407	11 as clean coal facilities. During the 2009 procurement
5408	5408	12 planning process and thereafter, the Agency and the
5409	5409	13 Commission shall consider sourcing agreements covering
5410	5410	14 electricity generated by power plants that were previously
5411	5411	15 owned by Illinois utilities and that have been or will be
5412	5412	16 converted into clean coal facilities, as defined by
5413	5413	17 Section 1-10 of this Act. Pursuant to such procurement
5414	5414	18 planning process, the owners of such facilities may
5415	5415	19 propose to the Agency sourcing agreements with utilities
5416	5416	20 and alternative retail electric suppliers required to
5417	5417	21 comply with subsection (d) of this Section and item (5) of
5418	5418	22 subsection (d) of Section 16-115 of the Public Utilities
5419	5419	23 Act, covering electricity generated by such facilities. In
5420	5420	24 the case of sourcing agreements that are power purchase
5421	5421	25 agreements, the contract price for electricity sales shall
5422	5422	26 be established on a cost of service basis. In the case of
5423	5423
5424	5424
5425	5425
5426	5426
5427	5427
5428	5428	SB1442 - 150 - LRB104 11424 BDA 21512 b
5429	5429
5430	5430
5431	5431	SB1442- 151 -LRB104 11424 BDA 21512 b SB1442 - 151 - LRB104 11424 BDA 21512 b
5432	5432	SB1442 - 151 - LRB104 11424 BDA 21512 b
5433	5433	1 sourcing agreements that are contracts for differences,
5434	5434	2 the contract price from which the reference price is
5435	5435	3 subtracted shall be established on a cost of service
5436	5436	4 basis. The Agency and the Commission may approve any such
5437	5437	5 utility sourcing agreements that do not exceed cost-based
5438	5438	6 benchmarks developed by the procurement administrator, in
5439	5439	7 consultation with the Commission staff, Agency staff and
5440	5440	8 the procurement monitor, subject to Commission review and
5441	5441	9 approval. The Commission shall have authority to inspect
5442	5442	10 all books and records associated with these clean coal
5443	5443	11 facilities during the term of any such contract.
5444	5444	12 (6) Costs incurred under this subsection (d) or
5445	5445	13 pursuant to a contract entered into under this subsection
5446	5446	14 (d) shall be deemed prudently incurred and reasonable in
5447	5447	15 amount and the electric utility shall be entitled to full
5448	5448	16 cost recovery pursuant to the tariffs filed with the
5449	5449	17 Commission.
5450	5450	18 (d-5) Zero emission standard.
5451	5451	19 (1) Beginning with the delivery year commencing on
5452	5452	20 June 1, 2017, the Agency shall, for electric utilities
5453	5453	21 that serve at least 100,000 retail customers in this
5454	5454	22 State, procure contracts with zero emission facilities
5455	5455	23 that are reasonably capable of generating cost-effective
5456	5456	24 zero emission credits in an amount approximately equal to
5457	5457	25 16% of the actual amount of electricity delivered by each
5458	5458	26 electric utility to retail customers in the State during
5459	5459
5460	5460
5461	5461
5462	5462
5463	5463
5464	5464	SB1442 - 151 - LRB104 11424 BDA 21512 b
5465	5465
5466	5466
5467	5467	SB1442- 152 -LRB104 11424 BDA 21512 b SB1442 - 152 - LRB104 11424 BDA 21512 b
5468	5468	SB1442 - 152 - LRB104 11424 BDA 21512 b
5469	5469	1 calendar year 2014. For an electric utility serving fewer
5470	5470	2 than 100,000 retail customers in this State that
5471	5471	3 requested, under Section 16-111.5 of the Public Utilities
5472	5472	4 Act, that the Agency procure power and energy for all or a
5473	5473	5 portion of the utility's Illinois load for the delivery
5474	5474	6 year commencing June 1, 2016, the Agency shall procure
5475	5475	7 contracts with zero emission facilities that are
5476	5476	8 reasonably capable of generating cost-effective zero
5477	5477	9 emission credits in an amount approximately equal to 16%
5478	5478	10 of the portion of power and energy to be procured by the
5479	5479	11 Agency for the utility. The duration of the contracts
5480	5480	12 procured under this subsection (d-5) shall be for a term
5481	5481	13 of 10 years ending May 31, 2027. The quantity of zero
5482	5482	14 emission credits to be procured under the contracts shall
5483	5483	15 be all of the zero emission credits generated by the zero
5484	5484	16 emission facility in each delivery year; however, if the
5485	5485	17 zero emission facility is owned by more than one entity,
5486	5486	18 then the quantity of zero emission credits to be procured
5487	5487	19 under the contracts shall be the amount of zero emission
5488	5488	20 credits that are generated from the portion of the zero
5489	5489	21 emission facility that is owned by the winning supplier.
5490	5490	22 The 16% value identified in this paragraph (1) is the
5491	5491	23 average of the percentage targets in subparagraph (B) of
5492	5492	24 paragraph (1) of subsection (c) of this Section for the 5
5493	5493	25 delivery years beginning June 1, 2017.
5494	5494	26 The procurement process shall be subject to the
5495	5495
5496	5496
5497	5497
5498	5498
5499	5499
5500	5500	SB1442 - 152 - LRB104 11424 BDA 21512 b
5501	5501
5502	5502
5503	5503	SB1442- 153 -LRB104 11424 BDA 21512 b SB1442 - 153 - LRB104 11424 BDA 21512 b
5504	5504	SB1442 - 153 - LRB104 11424 BDA 21512 b
5505	5505	1 following provisions:
5506	5506	2 (A) Those zero emission facilities that intend to
5507	5507	3 participate in the procurement shall submit to the
5508	5508	4 Agency the following eligibility information for each
5509	5509	5 zero emission facility on or before the date
5510	5510	6 established by the Agency:
5511	5511	7 (i) the in-service date and remaining useful
5512	5512	8 life of the zero emission facility;
5513	5513	9 (ii) the amount of power generated annually
5514	5514	10 for each of the years 2005 through 2015, and the
5515	5515	11 projected zero emission credits to be generated
5516	5516	12 over the remaining useful life of the zero
5517	5517	13 emission facility, which shall be used to
5518	5518	14 determine the capability of each facility;
5519	5519	15 (iii) the annual zero emission facility cost
5520	5520	16 projections, expressed on a per megawatthour
5521	5521	17 basis, over the next 6 delivery years, which shall
5522	5522	18 include the following: operation and maintenance
5523	5523	19 expenses; fully allocated overhead costs, which
5524	5524	20 shall be allocated using the methodology developed
5525	5525	21 by the Institute for Nuclear Power Operations;
5526	5526	22 fuel expenditures; non-fuel capital expenditures;
5527	5527	23 spent fuel expenditures; a return on working
5528	5528	24 capital; the cost of operational and market risks
5529	5529	25 that could be avoided by ceasing operation; and
5530	5530	26 any other costs necessary for continued
5531	5531
5532	5532
5533	5533
5534	5534
5535	5535
5536	5536	SB1442 - 153 - LRB104 11424 BDA 21512 b
5537	5537
5538	5538
5539	5539	SB1442- 154 -LRB104 11424 BDA 21512 b SB1442 - 154 - LRB104 11424 BDA 21512 b
5540	5540	SB1442 - 154 - LRB104 11424 BDA 21512 b
5541	5541	1 operations, provided that "necessary" means, for
5542	5542	2 purposes of this item (iii), that the costs could
5543	5543	3 reasonably be avoided only by ceasing operations
5544	5544	4 of the zero emission facility; and
5545	5545	5 (iv) a commitment to continue operating, for
5546	5546	6 the duration of the contract or contracts executed
5547	5547	7 under the procurement held under this subsection
5548	5548	8 (d-5), the zero emission facility that produces
5549	5549	9 the zero emission credits to be procured in the
5550	5550	10 procurement.
5551	5551	11 The information described in item (iii) of this
5552	5552	12 subparagraph (A) may be submitted on a confidential
5553	5553	13 basis and shall be treated and maintained by the
5554	5554	14 Agency, the procurement administrator, and the
5555	5555	15 Commission as confidential and proprietary and exempt
5556	5556	16 from disclosure under subparagraphs (a) and (g) of
5557	5557	17 paragraph (1) of Section 7 of the Freedom of
5558	5558	18 Information Act. The Office of Attorney General shall
5559	5559	19 have access to, and maintain the confidentiality of,
5560	5560	20 such information pursuant to Section 6.5 of the
5561	5561	21 Attorney General Act.
5562	5562	22 (B) The price for each zero emission credit
5563	5563	23 procured under this subsection (d-5) for each delivery
5564	5564	24 year shall be in an amount that equals the Social Cost
5565	5565	25 of Carbon, expressed on a price per megawatthour
5566	5566	26 basis. However, to ensure that the procurement remains
5567	5567
5568	5568
5569	5569
5570	5570
5571	5571
5572	5572	SB1442 - 154 - LRB104 11424 BDA 21512 b
5573	5573
5574	5574
5575	5575	SB1442- 155 -LRB104 11424 BDA 21512 b SB1442 - 155 - LRB104 11424 BDA 21512 b
5576	5576	SB1442 - 155 - LRB104 11424 BDA 21512 b
5577	5577	1 affordable to retail customers in this State if
5578	5578	2 electricity prices increase, the price in an
5579	5579	3 applicable delivery year shall be reduced below the
5580	5580	4 Social Cost of Carbon by the amount ("Price
5581	5581	5 Adjustment") by which the market price index for the
5582	5582	6 applicable delivery year exceeds the baseline market
5583	5583	7 price index for the consecutive 12-month period ending
5584	5584	8 May 31, 2016. If the Price Adjustment is greater than
5585	5585	9 or equal to the Social Cost of Carbon in an applicable
5586	5586	10 delivery year, then no payments shall be due in that
5587	5587	11 delivery year. The components of this calculation are
5588	5588	12 defined as follows:
5589	5589	13 (i) Social Cost of Carbon: The Social Cost of
5590	5590	14 Carbon is $16.50 per megawatthour, which is based
5591	5591	15 on the U.S. Interagency Working Group on Social
5592	5592	16 Cost of Carbon's price in the August 2016
5593	5593	17 Technical Update using a 3% discount rate,
5594	5594	18 adjusted for inflation for each year of the
5595	5595	19 program. Beginning with the delivery year
5596	5596	20 commencing June 1, 2023, the price per
5597	5597	21 megawatthour shall increase by $1 per
5598	5598	22 megawatthour, and continue to increase by an
5599	5599	23 additional $1 per megawatthour each delivery year
5600	5600	24 thereafter.
5601	5601	25 (ii) Baseline market price index: The baseline
5602	5602	26 market price index for the consecutive 12-month
5603	5603
5604	5604
5605	5605
5606	5606
5607	5607
5608	5608	SB1442 - 155 - LRB104 11424 BDA 21512 b
5609	5609
5610	5610
5611	5611	SB1442- 156 -LRB104 11424 BDA 21512 b SB1442 - 156 - LRB104 11424 BDA 21512 b
5612	5612	SB1442 - 156 - LRB104 11424 BDA 21512 b
5613	5613	1 period ending May 31, 2016 is $31.40 per
5614	5614	2 megawatthour, which is based on the sum of (aa)
5615	5615	3 the average day-ahead energy price across all
5616	5616	4 hours of such 12-month period at the PJM
5617	5617	5 Interconnection LLC Northern Illinois Hub, (bb)
5618	5618	6 50% multiplied by the Base Residual Auction, or
5619	5619	7 its successor, capacity price for the rest of the
5620	5620	8 RTO zone group determined by PJM Interconnection
5621	5621	9 LLC, divided by 24 hours per day, and (cc) 50%
5622	5622	10 multiplied by the Planning Resource Auction, or
5623	5623	11 its successor, capacity price for Zone 4
5624	5624	12 determined by the Midcontinent Independent System
5625	5625	13 Operator, Inc., divided by 24 hours per day.
5626	5626	14 (iii) Market price index: The market price
5627	5627	15 index for a delivery year shall be the sum of
5628	5628	16 projected energy prices and projected capacity
5629	5629	17 prices determined as follows:
5630	5630	18 (aa) Projected energy prices: the
5631	5631	19 projected energy prices for the applicable
5632	5632	20 delivery year shall be calculated once for the
5633	5633	21 year using the forward market price for the
5634	5634	22 PJM Interconnection, LLC Northern Illinois
5635	5635	23 Hub. The forward market price shall be
5636	5636	24 calculated as follows: the energy forward
5637	5637	25 prices for each month of the applicable
5638	5638	26 delivery year averaged for each trade date
5639	5639
5640	5640
5641	5641
5642	5642
5643	5643
5644	5644	SB1442 - 156 - LRB104 11424 BDA 21512 b
5645	5645
5646	5646
5647	5647	SB1442- 157 -LRB104 11424 BDA 21512 b SB1442 - 157 - LRB104 11424 BDA 21512 b
5648	5648	SB1442 - 157 - LRB104 11424 BDA 21512 b
5649	5649	1 during the calendar year immediately preceding
5650	5650	2 that delivery year to produce a single energy
5651	5651	3 forward price for the delivery year. The
5652	5652	4 forward market price calculation shall use
5653	5653	5 data published by the Intercontinental
5654	5654	6 Exchange, or its successor.
5655	5655	7 (bb) Projected capacity prices:
5656	5656	8 (I) For the delivery years commencing
5657	5657	9 June 1, 2017, June 1, 2018, and June 1,
5658	5658	10 2019, the projected capacity price shall
5659	5659	11 be equal to the sum of (1) 50% multiplied
5660	5660	12 by the Base Residual Auction, or its
5661	5661	13 successor, price for the rest of the RTO
5662	5662	14 zone group as determined by PJM
5663	5663	15 Interconnection LLC, divided by 24 hours
5664	5664	16 per day and, (2) 50% multiplied by the
5665	5665	17 resource auction price determined in the
5666	5666	18 resource auction administered by the
5667	5667	19 Midcontinent Independent System Operator,
5668	5668	20 Inc., in which the largest percentage of
5669	5669	21 load cleared for Local Resource Zone 4,
5670	5670	22 divided by 24 hours per day, and where
5671	5671	23 such price is determined by the
5672	5672	24 Midcontinent Independent System Operator,
5673	5673	25 Inc.
5674	5674	26 (II) For the delivery year commencing
5675	5675
5676	5676
5677	5677
5678	5678
5679	5679
5680	5680	SB1442 - 157 - LRB104 11424 BDA 21512 b
5681	5681
5682	5682
5683	5683	SB1442- 158 -LRB104 11424 BDA 21512 b SB1442 - 158 - LRB104 11424 BDA 21512 b
5684	5684	SB1442 - 158 - LRB104 11424 BDA 21512 b
5685	5685	1 June 1, 2020, and each year thereafter,
5686	5686	2 the projected capacity price shall be
5687	5687	3 equal to the sum of (1) 50% multiplied by
5688	5688	4 the Base Residual Auction, or its
5689	5689	5 successor, price for the ComEd zone as
5690	5690	6 determined by PJM Interconnection LLC,
5691	5691	7 divided by 24 hours per day, and (2) 50%
5692	5692	8 multiplied by the resource auction price
5693	5693	9 determined in the resource auction
5694	5694	10 administered by the Midcontinent
5695	5695	11 Independent System Operator, Inc., in
5696	5696	12 which the largest percentage of load
5697	5697	13 cleared for Local Resource Zone 4, divided
5698	5698	14 by 24 hours per day, and where such price
5699	5699	15 is determined by the Midcontinent
5700	5700	16 Independent System Operator, Inc.
5701	5701	17 For purposes of this subsection (d-5):
5702	5702	18 "Rest of the RTO" and "ComEd Zone" shall have
5703	5703	19 the meaning ascribed to them by PJM
5704	5704	20 Interconnection, LLC.
5705	5705	21 "RTO" means regional transmission
5706	5706	22 organization.
5707	5707	23 (C) No later than 45 days after June 1, 2017 (the
5708	5708	24 effective date of Public Act 99-906), the Agency shall
5709	5709	25 publish its proposed zero emission standard
5710	5710	26 procurement plan. The plan shall be consistent with
5711	5711
5712	5712
5713	5713
5714	5714
5715	5715
5716	5716	SB1442 - 158 - LRB104 11424 BDA 21512 b
5717	5717
5718	5718
5719	5719	SB1442- 159 -LRB104 11424 BDA 21512 b SB1442 - 159 - LRB104 11424 BDA 21512 b
5720	5720	SB1442 - 159 - LRB104 11424 BDA 21512 b
5721	5721	1 the provisions of this paragraph (1) and shall provide
5722	5722	2 that winning bids shall be selected based on public
5723	5723	3 interest criteria that include, but are not limited
5724	5724	4 to, minimizing carbon dioxide emissions that result
5725	5725	5 from electricity consumed in Illinois and minimizing
5726	5726	6 sulfur dioxide, nitrogen oxide, and particulate matter
5727	5727	7 emissions that adversely affect the citizens of this
5728	5728	8 State. In particular, the selection of winning bids
5729	5729	9 shall take into account the incremental environmental
5730	5730	10 benefits resulting from the procurement, such as any
5731	5731	11 existing environmental benefits that are preserved by
5732	5732	12 the procurements held under Public Act 99-906 and
5733	5733	13 would cease to exist if the procurements were not
5734	5734	14 held, including the preservation of zero emission
5735	5735	15 facilities. The plan shall also describe in detail how
5736	5736	16 each public interest factor shall be considered and
5737	5737	17 weighted in the bid selection process to ensure that
5738	5738	18 the public interest criteria are applied to the
5739	5739	19 procurement and given full effect.
5740	5740	20 For purposes of developing the plan, the Agency
5741	5741	21 shall consider any reports issued by a State agency,
5742	5742	22 board, or commission under House Resolution 1146 of
5743	5743	23 the 98th General Assembly and paragraph (4) of
5744	5744	24 subsection (d) of this Section, as well as publicly
5745	5745	25 available analyses and studies performed by or for
5746	5746	26 regional transmission organizations that serve the
5747	5747
5748	5748
5749	5749
5750	5750
5751	5751
5752	5752	SB1442 - 159 - LRB104 11424 BDA 21512 b
5753	5753
5754	5754
5755	5755	SB1442- 160 -LRB104 11424 BDA 21512 b SB1442 - 160 - LRB104 11424 BDA 21512 b
5756	5756	SB1442 - 160 - LRB104 11424 BDA 21512 b
5757	5757	1 State and their independent market monitors.
5758	5758	2 Upon publishing of the zero emission standard
5759	5759	3 procurement plan, copies of the plan shall be posted
5760	5760	4 and made publicly available on the Agency's website.
5761	5761	5 All interested parties shall have 10 days following
5762	5762	6 the date of posting to provide comment to the Agency on
5763	5763	7 the plan. All comments shall be posted to the Agency's
5764	5764	8 website. Following the end of the comment period, but
5765	5765	9 no more than 60 days later than June 1, 2017 (the
5766	5766	10 effective date of Public Act 99-906), the Agency shall
5767	5767	11 revise the plan as necessary based on the comments
5768	5768	12 received and file its zero emission standard
5769	5769	13 procurement plan with the Commission.
5770	5770	14 If the Commission determines that the plan will
5771	5771	15 result in the procurement of cost-effective zero
5772	5772	16 emission credits, then the Commission shall, after
5773	5773	17 notice and hearing, but no later than 45 days after the
5774	5774	18 Agency filed the plan, approve the plan or approve
5775	5775	19 with modification. For purposes of this subsection
5776	5776	20 (d-5), "cost effective" means the projected costs of
5777	5777	21 procuring zero emission credits from zero emission
5778	5778	22 facilities do not cause the limit stated in paragraph
5779	5779	23 (2) of this subsection to be exceeded.
5780	5780	24 (C-5) As part of the Commission's review and
5781	5781	25 acceptance or rejection of the procurement results,
5782	5782	26 the Commission shall, in its public notice of
5783	5783
5784	5784
5785	5785
5786	5786
5787	5787
5788	5788	SB1442 - 160 - LRB104 11424 BDA 21512 b
5789	5789
5790	5790
5791	5791	SB1442- 161 -LRB104 11424 BDA 21512 b SB1442 - 161 - LRB104 11424 BDA 21512 b
5792	5792	SB1442 - 161 - LRB104 11424 BDA 21512 b
5793	5793	1 successful bidders:
5794	5794	2 (i) identify how the winning bids satisfy the
5795	5795	3 public interest criteria described in subparagraph
5796	5796	4 (C) of this paragraph (1) of minimizing carbon
5797	5797	5 dioxide emissions that result from electricity
5798	5798	6 consumed in Illinois and minimizing sulfur
5799	5799	7 dioxide, nitrogen oxide, and particulate matter
5800	5800	8 emissions that adversely affect the citizens of
5801	5801	9 this State;
5802	5802	10 (ii) specifically address how the selection of
5803	5803	11 winning bids takes into account the incremental
5804	5804	12 environmental benefits resulting from the
5805	5805	13 procurement, including any existing environmental
5806	5806	14 benefits that are preserved by the procurements
5807	5807	15 held under Public Act 99-906 and would have ceased
5808	5808	16 to exist if the procurements had not been held,
5809	5809	17 such as the preservation of zero emission
5810	5810	18 facilities;
5811	5811	19 (iii) quantify the environmental benefit of
5812	5812	20 preserving the resources identified in item (ii)
5813	5813	21 of this subparagraph (C-5), including the
5814	5814	22 following:
5815	5815	23 (aa) the value of avoided greenhouse gas
5816	5816	24 emissions measured as the product of the zero
5817	5817	25 emission facilities' output over the contract
5818	5818	26 term multiplied by the U.S. Environmental
5819	5819
5820	5820
5821	5821
5822	5822
5823	5823
5824	5824	SB1442 - 161 - LRB104 11424 BDA 21512 b
5825	5825
5826	5826
5827	5827	SB1442- 162 -LRB104 11424 BDA 21512 b SB1442 - 162 - LRB104 11424 BDA 21512 b
5828	5828	SB1442 - 162 - LRB104 11424 BDA 21512 b
5829	5829	1 Protection Agency eGrid subregion carbon
5830	5830	2 dioxide emission rate and the U.S. Interagency
5831	5831	3 Working Group on Social Cost of Carbon's price
5832	5832	4 in the August 2016 Technical Update using a 3%
5833	5833	5 discount rate, adjusted for inflation for each
5834	5834	6 delivery year; and
5835	5835	7 (bb) the costs of replacement with other
5836	5836	8 zero carbon dioxide resources, including wind
5837	5837	9 and photovoltaic, based upon the simple
5838	5838	10 average of the following:
5839	5839	11 (I) the price, or if there is more
5840	5840	12 than one price, the average of the prices,
5841	5841	13 paid for renewable energy credits from new
5842	5842	14 utility-scale wind projects in the
5843	5843	15 procurement events specified in item (i)
5844	5844	16 of subparagraph (G) of paragraph (1) of
5845	5845	17 subsection (c) of this Section; and
5846	5846	18 (II) the price, or if there is more
5847	5847	19 than one price, the average of the prices,
5848	5848	20 paid for renewable energy credits from new
5849	5849	21 utility-scale solar projects and
5850	5850	22 brownfield site photovoltaic projects in
5851	5851	23 the procurement events specified in item
5852	5852	24 (ii) of subparagraph (G) of paragraph (1)
5853	5853	25 of subsection (c) of this Section and,
5854	5854	26 after January 1, 2015, renewable energy
5855	5855
5856	5856
5857	5857
5858	5858
5859	5859
5860	5860	SB1442 - 162 - LRB104 11424 BDA 21512 b
5861	5861
5862	5862
5863	5863	SB1442- 163 -LRB104 11424 BDA 21512 b SB1442 - 163 - LRB104 11424 BDA 21512 b
5864	5864	SB1442 - 163 - LRB104 11424 BDA 21512 b
5865	5865	1 credits from photovoltaic distributed
5866	5866	2 generation projects in procurement events
5867	5867	3 held under subsection (c) of this Section.
5868	5868	4 Each utility shall enter into binding contractual
5869	5869	5 arrangements with the winning suppliers.
5870	5870	6 The procurement described in this subsection
5871	5871	7 (d-5), including, but not limited to, the execution of
5872	5872	8 all contracts procured, shall be completed no later
5873	5873	9 than May 10, 2017. Based on the effective date of
5874	5874	10 Public Act 99-906, the Agency and Commission may, as
5875	5875	11 appropriate, modify the various dates and timelines
5876	5876	12 under this subparagraph and subparagraphs (C) and (D)
5877	5877	13 of this paragraph (1). The procurement and plan
5878	5878	14 approval processes required by this subsection (d-5)
5879	5879	15 shall be conducted in conjunction with the procurement
5880	5880	16 and plan approval processes required by subsection (c)
5881	5881	17 of this Section and Section 16-111.5 of the Public
5882	5882	18 Utilities Act, to the extent practicable.
5883	5883	19 Notwithstanding whether a procurement event is
5884	5884	20 conducted under Section 16-111.5 of the Public
5885	5885	21 Utilities Act, the Agency shall immediately initiate a
5886	5886	22 procurement process on June 1, 2017 (the effective
5887	5887	23 date of Public Act 99-906).
5888	5888	24 (D) Following the procurement event described in
5889	5889	25 this paragraph (1) and consistent with subparagraph
5890	5890	26 (B) of this paragraph (1), the Agency shall calculate
5891	5891
5892	5892
5893	5893
5894	5894
5895	5895
5896	5896	SB1442 - 163 - LRB104 11424 BDA 21512 b
5897	5897
5898	5898
5899	5899	SB1442- 164 -LRB104 11424 BDA 21512 b SB1442 - 164 - LRB104 11424 BDA 21512 b
5900	5900	SB1442 - 164 - LRB104 11424 BDA 21512 b
5901	5901	1 the payments to be made under each contract for the
5902	5902	2 next delivery year based on the market price index for
5903	5903	3 that delivery year. The Agency shall publish the
5904	5904	4 payment calculations no later than May 25, 2017 and
5905	5905	5 every May 25 thereafter.
5906	5906	6 (E) Notwithstanding the requirements of this
5907	5907	7 subsection (d-5), the contracts executed under this
5908	5908	8 subsection (d-5) shall provide that the zero emission
5909	5909	9 facility may, as applicable, suspend or terminate
5910	5910	10 performance under the contracts in the following
5911	5911	11 instances:
5912	5912	12 (i) A zero emission facility shall be excused
5913	5913	13 from its performance under the contract for any
5914	5914	14 cause beyond the control of the resource,
5915	5915	15 including, but not restricted to, acts of God,
5916	5916	16 flood, drought, earthquake, storm, fire,
5917	5917	17 lightning, epidemic, war, riot, civil disturbance
5918	5918	18 or disobedience, labor dispute, labor or material
5919	5919	19 shortage, sabotage, acts of public enemy,
5920	5920	20 explosions, orders, regulations or restrictions
5921	5921	21 imposed by governmental, military, or lawfully
5922	5922	22 established civilian authorities, which, in any of
5923	5923	23 the foregoing cases, by exercise of commercially
5924	5924	24 reasonable efforts the zero emission facility
5925	5925	25 could not reasonably have been expected to avoid,
5926	5926	26 and which, by the exercise of commercially
5927	5927
5928	5928
5929	5929
5930	5930
5931	5931
5932	5932	SB1442 - 164 - LRB104 11424 BDA 21512 b
5933	5933
5934	5934
5935	5935	SB1442- 165 -LRB104 11424 BDA 21512 b SB1442 - 165 - LRB104 11424 BDA 21512 b
5936	5936	SB1442 - 165 - LRB104 11424 BDA 21512 b
5937	5937	1 reasonable efforts, it has been unable to
5938	5938	2 overcome. In such event, the zero emission
5939	5939	3 facility shall be excused from performance for the
5940	5940	4 duration of the event, including, but not limited
5941	5941	5 to, delivery of zero emission credits, and no
5942	5942	6 payment shall be due to the zero emission facility
5943	5943	7 during the duration of the event.
5944	5944	8 (ii) A zero emission facility shall be
5945	5945	9 permitted to terminate the contract if legislation
5946	5946	10 is enacted into law by the General Assembly that
5947	5947	11 imposes or authorizes a new tax, special
5948	5948	12 assessment, or fee on the generation of
5949	5949	13 electricity, the ownership or leasehold of a
5950	5950	14 generating unit, or the privilege or occupation of
5951	5951	15 such generation, ownership, or leasehold of
5952	5952	16 generation units by a zero emission facility.
5953	5953	17 However, the provisions of this item (ii) do not
5954	5954	18 apply to any generally applicable tax, special
5955	5955	19 assessment or fee, or requirements imposed by
5956	5956	20 federal law.
5957	5957	21 (iii) A zero emission facility shall be
5958	5958	22 permitted to terminate the contract in the event
5959	5959	23 that the resource requires capital expenditures in
5960	5960	24 excess of $40,000,000 that were neither known nor
5961	5961	25 reasonably foreseeable at the time it executed the
5962	5962	26 contract and that a prudent owner or operator of
5963	5963
5964	5964
5965	5965
5966	5966
5967	5967
5968	5968	SB1442 - 165 - LRB104 11424 BDA 21512 b
5969	5969
5970	5970
5971	5971	SB1442- 166 -LRB104 11424 BDA 21512 b SB1442 - 166 - LRB104 11424 BDA 21512 b
5972	5972	SB1442 - 166 - LRB104 11424 BDA 21512 b
5973	5973	1 such resource would not undertake.
5974	5974	2 (iv) A zero emission facility shall be
5975	5975	3 permitted to terminate the contract in the event
5976	5976	4 the Nuclear Regulatory Commission terminates the
5977	5977	5 resource's license.
5978	5978	6 (F) If the zero emission facility elects to
5979	5979	7 terminate a contract under subparagraph (E) of this
5980	5980	8 paragraph (1), then the Commission shall reopen the
5981	5981	9 docket in which the Commission approved the zero
5982	5982	10 emission standard procurement plan under subparagraph
5983	5983	11 (C) of this paragraph (1) and, after notice and
5984	5984	12 hearing, enter an order acknowledging the contract
5985	5985	13 termination election if such termination is consistent
5986	5986	14 with the provisions of this subsection (d-5).
5987	5987	15 (2) For purposes of this subsection (d-5), the amount
5988	5988	16 paid per kilowatthour means the total amount paid for
5989	5989	17 electric service expressed on a per kilowatthour basis.
5990	5990	18 For purposes of this subsection (d-5), the total amount
5991	5991	19 paid for electric service includes, without limitation,
5992	5992	20 amounts paid for supply, transmission, distribution,
5993	5993	21 surcharges, and add-on taxes.
5994	5994	22 Notwithstanding the requirements of this subsection
5995	5995	23 (d-5), the contracts executed under this subsection (d-5)
5996	5996	24 shall provide that the total of zero emission credits
5997	5997	25 procured under a procurement plan shall be subject to the
5998	5998	26 limitations of this paragraph (2). For each delivery year,
5999	5999
6000	6000
6001	6001
6002	6002
6003	6003
6004	6004	SB1442 - 166 - LRB104 11424 BDA 21512 b
6005	6005
6006	6006
6007	6007	SB1442- 167 -LRB104 11424 BDA 21512 b SB1442 - 167 - LRB104 11424 BDA 21512 b
6008	6008	SB1442 - 167 - LRB104 11424 BDA 21512 b
6009	6009	1 the contractual volume receiving payments in such year
6010	6010	2 shall be reduced for all retail customers based on the
6011	6011	3 amount necessary to limit the net increase that delivery
6012	6012	4 year to the costs of those credits included in the amounts
6013	6013	5 paid by eligible retail customers in connection with
6014	6014	6 electric service to no more than 1.65% of the amount paid
6015	6015	7 per kilowatthour by eligible retail customers during the
6016	6016	8 year ending May 31, 2009. The result of this computation
6017	6017	9 shall apply to and reduce the procurement for all retail
6018	6018	10 customers, and all those customers shall pay the same
6019	6019	11 single, uniform cents per kilowatthour charge under
6020	6020	12 subsection (k) of Section 16-108 of the Public Utilities
6021	6021	13 Act. To arrive at a maximum dollar amount of zero emission
6022	6022	14 credits to be paid for the particular delivery year, the
6023	6023	15 resulting per kilowatthour amount shall be applied to the
6024	6024	16 actual amount of kilowatthours of electricity delivered by
6025	6025	17 the electric utility in the delivery year immediately
6026	6026	18 prior to the procurement, to all retail customers in its
6027	6027	19 service territory. Unpaid contractual volume for any
6028	6028	20 delivery year shall be paid in any subsequent delivery
6029	6029	21 year in which such payments can be made without exceeding
6030	6030	22 the amount specified in this paragraph (2). The
6031	6031	23 calculations required by this paragraph (2) shall be made
6032	6032	24 only once for each procurement plan year. Once the
6033	6033	25 determination as to the amount of zero emission credits to
6034	6034	26 be paid is made based on the calculations set forth in this
6035	6035
6036	6036
6037	6037
6038	6038
6039	6039
6040	6040	SB1442 - 167 - LRB104 11424 BDA 21512 b
6041	6041
6042	6042
6043	6043	SB1442- 168 -LRB104 11424 BDA 21512 b SB1442 - 168 - LRB104 11424 BDA 21512 b
6044	6044	SB1442 - 168 - LRB104 11424 BDA 21512 b
6045	6045	1 paragraph (2), no subsequent rate impact determinations
6046	6046	2 shall be made and no adjustments to those contract amounts
6047	6047	3 shall be allowed. All costs incurred under those contracts
6048	6048	4 and in implementing this subsection (d-5) shall be
6049	6049	5 recovered by the electric utility as provided in this
6050	6050	6 Section.
6051	6051	7 No later than June 30, 2019, the Commission shall
6052	6052	8 review the limitation on the amount of zero emission
6053	6053	9 credits procured under this subsection (d-5) and report to
6054	6054	10 the General Assembly its findings as to whether that
6055	6055	11 limitation unduly constrains the procurement of
6056	6056	12 cost-effective zero emission credits.
6057	6057	13 (3) Six years after the execution of a contract under
6058	6058	14 this subsection (d-5), the Agency shall determine whether
6059	6059	15 the actual zero emission credit payments received by the
6060	6060	16 supplier over the 6-year period exceed the Average ZEC
6061	6061	17 Payment. In addition, at the end of the term of a contract
6062	6062	18 executed under this subsection (d-5), or at the time, if
6063	6063	19 any, a zero emission facility's contract is terminated
6064	6064	20 under subparagraph (E) of paragraph (1) of this subsection
6065	6065	21 (d-5), then the Agency shall determine whether the actual
6066	6066	22 zero emission credit payments received by the supplier
6067	6067	23 over the term of the contract exceed the Average ZEC
6068	6068	24 Payment, after taking into account any amounts previously
6069	6069	25 credited back to the utility under this paragraph (3). If
6070	6070	26 the Agency determines that the actual zero emission credit
6071	6071
6072	6072
6073	6073
6074	6074
6075	6075
6076	6076	SB1442 - 168 - LRB104 11424 BDA 21512 b
6077	6077
6078	6078
6079	6079	SB1442- 169 -LRB104 11424 BDA 21512 b SB1442 - 169 - LRB104 11424 BDA 21512 b
6080	6080	SB1442 - 169 - LRB104 11424 BDA 21512 b
6081	6081	1 payments received by the supplier over the relevant period
6082	6082	2 exceed the Average ZEC Payment, then the supplier shall
6083	6083	3 credit the difference back to the utility. The amount of
6084	6084	4 the credit shall be remitted to the applicable electric
6085	6085	5 utility no later than 120 days after the Agency's
6086	6086	6 determination, which the utility shall reflect as a credit
6087	6087	7 on its retail customer bills as soon as practicable;
6088	6088	8 however, the credit remitted to the utility shall not
6089	6089	9 exceed the total amount of payments received by the
6090	6090	10 facility under its contract.
6091	6091	11 For purposes of this Section, the Average ZEC Payment
6092	6092	12 shall be calculated by multiplying the quantity of zero
6093	6093	13 emission credits delivered under the contract times the
6094	6094	14 average contract price. The average contract price shall
6095	6095	15 be determined by subtracting the amount calculated under
6096	6096	16 subparagraph (B) of this paragraph (3) from the amount
6097	6097	17 calculated under subparagraph (A) of this paragraph (3),
6098	6098	18 as follows:
6099	6099	19 (A) The average of the Social Cost of Carbon, as
6100	6100	20 defined in subparagraph (B) of paragraph (1) of this
6101	6101	21 subsection (d-5), during the term of the contract.
6102	6102	22 (B) The average of the market price indices, as
6103	6103	23 defined in subparagraph (B) of paragraph (1) of this
6104	6104	24 subsection (d-5), during the term of the contract,
6105	6105	25 minus the baseline market price index, as defined in
6106	6106	26 subparagraph (B) of paragraph (1) of this subsection
6107	6107
6108	6108
6109	6109
6110	6110
6111	6111
6112	6112	SB1442 - 169 - LRB104 11424 BDA 21512 b
6113	6113
6114	6114
6115	6115	SB1442- 170 -LRB104 11424 BDA 21512 b SB1442 - 170 - LRB104 11424 BDA 21512 b
6116	6116	SB1442 - 170 - LRB104 11424 BDA 21512 b
6117	6117	1 (d-5).
6118	6118	2 If the subtraction yields a negative number, then the
6119	6119	3 Average ZEC Payment shall be zero.
6120	6120	4 (4) Cost-effective zero emission credits procured from
6121	6121	5 zero emission facilities shall satisfy the applicable
6122	6122	6 definitions set forth in Section 1-10 of this Act.
6123	6123	7 (5) The electric utility shall retire all zero
6124	6124	8 emission credits used to comply with the requirements of
6125	6125	9 this subsection (d-5).
6126	6126	10 (6) Electric utilities shall be entitled to recover
6127	6127	11 all of the costs associated with the procurement of zero
6128	6128	12 emission credits through an automatic adjustment clause
6129	6129	13 tariff in accordance with subsection (k) and (m) of
6130	6130	14 Section 16-108 of the Public Utilities Act, and the
6131	6131	15 contracts executed under this subsection (d-5) shall
6132	6132	16 provide that the utilities' payment obligations under such
6133	6133	17 contracts shall be reduced if an adjustment is required
6134	6134	18 under subsection (m) of Section 16-108 of the Public
6135	6135	19 Utilities Act.
6136	6136	20 (7) This subsection (d-5) shall become inoperative on
6137	6137	21 January 1, 2028.
6138	6138	22 (d-10) Nuclear Plant Assistance; carbon mitigation
6139	6139	23 credits.
6140	6140	24 (1) The General Assembly finds:
6141	6141	25 (A) The health, welfare, and prosperity of all
6142	6142	26 Illinois citizens require that the State of Illinois act
6143	6143
6144	6144
6145	6145
6146	6146
6147	6147
6148	6148	SB1442 - 170 - LRB104 11424 BDA 21512 b
6149	6149
6150	6150
6151	6151	SB1442- 171 -LRB104 11424 BDA 21512 b SB1442 - 171 - LRB104 11424 BDA 21512 b
6152	6152	SB1442 - 171 - LRB104 11424 BDA 21512 b
6153	6153	1 to avoid and not increase carbon emissions from electric
6154	6154	2 generation sources while continuing to ensure affordable,
6155	6155	3 stable, and reliable electricity to all citizens.
6156	6156	4 (B) Absent immediate action by the State to preserve
6157	6157	5 existing carbon-free energy resources, those resources may
6158	6158	6 retire, and the electric generation needs of Illinois'
6159	6159	7 retail customers may be met instead by facilities that
6160	6160	8 emit significant amounts of carbon pollution and other
6161	6161	9 harmful air pollutants at a high social and economic cost
6162	6162	10 until Illinois is able to develop other forms of clean
6163	6163	11 energy.
6164	6164	12 (C) The General Assembly finds that nuclear power
6165	6165	13 generation is necessary for the State's transition to 100%
6166	6166	14 clean energy, and ensuring continued operation of nuclear
6167	6167	15 plants advances environmental and public health interests
6168	6168	16 through providing carbon-free electricity while reducing
6169	6169	17 the air pollution profile of the Illinois energy
6170	6170	18 generation fleet.
6171	6171	19 (D) The clean energy attributes of nuclear generation
6172	6172	20 facilities support the State in its efforts to achieve
6173	6173	21 100% clean energy.
6174	6174	22 (E) The State currently invests in various forms of
6175	6175	23 clean energy, including, but not limited to, renewable
6176	6176	24 energy, energy efficiency, and low-emission vehicles,
6177	6177	25 among others.
6178	6178	26 (F) The Environmental Protection Agency commissioned
6179	6179
6180	6180
6181	6181
6182	6182
6183	6183
6184	6184	SB1442 - 171 - LRB104 11424 BDA 21512 b
6185	6185
6186	6186
6187	6187	SB1442- 172 -LRB104 11424 BDA 21512 b SB1442 - 172 - LRB104 11424 BDA 21512 b
6188	6188	SB1442 - 172 - LRB104 11424 BDA 21512 b
6189	6189	1 an independent audit which provided a detailed assessment
6190	6190	2 of the financial condition of the Illinois nuclear fleet
6191	6191	3 to evaluate its financial viability and whether the
6192	6192	4 environmental benefits of such resources were at risk. The
6193	6193	5 report identified the risk of losing the environmental
6194	6194	6 benefits of several specific nuclear units. The report
6195	6195	7 also identified that the LaSalle County Generating Station
6196	6196	8 will continue to operate through 2026 and therefore is not
6197	6197	9 eligible to participate in the carbon mitigation credit
6198	6198	10 program.
6199	6199	11 (G) Nuclear plants provide carbon-free energy, which
6200	6200	12 helps to avoid many health-related negative impacts for
6201	6201	13 Illinois residents.
6202	6202	14 (H) The procurement of carbon mitigation credits
6203	6203	15 representing the environmental benefits of carbon-free
6204	6204	16 generation will further the State's efforts at achieving
6205	6205	17 100% clean energy and decarbonizing the electricity sector
6206	6206	18 in a safe, reliable, and affordable manner. Further, the
6207	6207	19 procurement of carbon emission credits will enhance the
6208	6208	20 health and welfare of Illinois residents through decreased
6209	6209	21 reliance on more highly polluting generation.
6210	6210	22 (I) The General Assembly therefore finds it necessary
6211	6211	23 to establish carbon mitigation credits to ensure decreased
6212	6212	24 reliance on more carbon-intensive energy resources, for
6213	6213	25 transitioning to a fully decarbonized electricity sector,
6214	6214	26 and to help ensure health and welfare of the State's
6215	6215
6216	6216
6217	6217
6218	6218
6219	6219
6220	6220	SB1442 - 172 - LRB104 11424 BDA 21512 b
6221	6221
6222	6222
6223	6223	SB1442- 173 -LRB104 11424 BDA 21512 b SB1442 - 173 - LRB104 11424 BDA 21512 b
6224	6224	SB1442 - 173 - LRB104 11424 BDA 21512 b
6225	6225	1 residents.
6226	6226	2 (2) As used in this subsection:
6227	6227	3 "Baseline costs" means costs used to establish a customer
6228	6228	4 protection cap that have been evaluated through an independent
6229	6229	5 audit of a carbon-free energy resource conducted by the
6230	6230	6 Environmental Protection Agency that evaluated projected
6231	6231	7 annual costs for operation and maintenance expenses; fully
6232	6232	8 allocated overhead costs, which shall be allocated using the
6233	6233	9 methodology developed by the Institute for Nuclear Power
6234	6234	10 Operations; fuel expenditures; nonfuel capital expenditures;
6235	6235	11 spent fuel expenditures; a return on working capital; the cost
6236	6236	12 of operational and market risks that could be avoided by
6237	6237	13 ceasing operation; and any other costs necessary for continued
6238	6238	14 operations, provided that "necessary" means, for purposes of
6239	6239	15 this definition, that the costs could reasonably be avoided
6240	6240	16 only by ceasing operations of the carbon-free energy resource.
6241	6241	17 "Carbon mitigation credit" means a tradable credit that
6242	6242	18 represents the carbon emission reduction attributes of one
6243	6243	19 megawatt-hour of energy produced from a carbon-free energy
6244	6244	20 resource.
6245	6245	21 "Carbon-free energy resource" means a generation facility
6246	6246	22 that: (1) is fueled by nuclear power; and (2) is
6247	6247	23 interconnected to PJM Interconnection, LLC.
6248	6248	24 (3) Procurement.
6249	6249	25 (A) Beginning with the delivery year commencing on
6250	6250	26 June 1, 2022, the Agency shall, for electric utilities
6251	6251
6252	6252
6253	6253
6254	6254
6255	6255
6256	6256	SB1442 - 173 - LRB104 11424 BDA 21512 b
6257	6257
6258	6258
6259	6259	SB1442- 174 -LRB104 11424 BDA 21512 b SB1442 - 174 - LRB104 11424 BDA 21512 b
6260	6260	SB1442 - 174 - LRB104 11424 BDA 21512 b
6261	6261	1 serving at least 3,000,000 retail customers in the State,
6262	6262	2 seek to procure contracts for no more than approximately
6263	6263	3 54,500,000 cost-effective carbon mitigation credits from
6264	6264	4 carbon-free energy resources because such credits are
6265	6265	5 necessary to support current levels of carbon-free energy
6266	6266	6 generation and ensure the State meets its carbon dioxide
6267	6267	7 emissions reduction goals. The Agency shall not make a
6268	6268	8 partial award of a contract for carbon mitigation credits
6269	6269	9 covering a fractional amount of a carbon-free energy
6270	6270	10 resource's projected output.
6271	6271	11 (B) Each carbon-free energy resource that intends to
6272	6272	12 participate in a procurement shall be required to submit
6273	6273	13 to the Agency the following information for the resource
6274	6274	14 on or before the date established by the Agency:
6275	6275	15 (i) the in-service date and remaining useful life
6276	6276	16 of the carbon-free energy resource;
6277	6277	17 (ii) the amount of power generated annually for
6278	6278	18 each of the past 10 years, which shall be used to
6279	6279	19 determine the capability of each facility;
6280	6280	20 (iii) a commitment to be reflected in any contract
6281	6281	21 entered into pursuant to this subsection (d-10) to
6282	6282	22 continue operating the carbon-free energy resource at
6283	6283	23 a capacity factor of at least 88% annually on average
6284	6284	24 for the duration of the contract or contracts executed
6285	6285	25 under the procurement held under this subsection
6286	6286	26 (d-10), except in an instance described in
6287	6287
6288	6288
6289	6289
6290	6290
6291	6291
6292	6292	SB1442 - 174 - LRB104 11424 BDA 21512 b
6293	6293
6294	6294
6295	6295	SB1442- 175 -LRB104 11424 BDA 21512 b SB1442 - 175 - LRB104 11424 BDA 21512 b
6296	6296	SB1442 - 175 - LRB104 11424 BDA 21512 b
6297	6297	1 subparagraph (E) of paragraph (1) of subsection (d-5)
6298	6298	2 of this Section or made impracticable as a result of
6299	6299	3 compliance with law or regulation;
6300	6300	4 (iv) financial need and the risk of loss of the
6301	6301	5 environmental benefits of such resource, which shall
6302	6302	6 include the following information:
6303	6303	7 (I) the carbon-free energy resource's cost
6304	6304	8 projections, expressed on a per megawatt-hour
6305	6305	9 basis, over the next 5 delivery years, which shall
6306	6306	10 include the following: operation and maintenance
6307	6307	11 expenses; fully allocated overhead costs, which
6308	6308	12 shall be allocated using the methodology developed
6309	6309	13 by the Institute for Nuclear Power Operations;
6310	6310	14 fuel expenditures; nonfuel capital expenditures;
6311	6311	15 spent fuel expenditures; a return on working
6312	6312	16 capital; the cost of operational and market risks
6313	6313	17 that could be avoided by ceasing operation; and
6314	6314	18 any other costs necessary for continued
6315	6315	19 operations, provided that "necessary" means, for
6316	6316	20 purposes of this subitem (I), that the costs could
6317	6317	21 reasonably be avoided only by ceasing operations
6318	6318	22 of the carbon-free energy resource; and
6319	6319	23 (II) the carbon-free energy resource's revenue
6320	6320	24 projections, including energy, capacity, ancillary
6321	6321	25 services, any other direct State support, known or
6322	6322	26 anticipated federal attribute credits, known or
6323	6323
6324	6324
6325	6325
6326	6326
6327	6327
6328	6328	SB1442 - 175 - LRB104 11424 BDA 21512 b
6329	6329
6330	6330
6331	6331	SB1442- 176 -LRB104 11424 BDA 21512 b SB1442 - 176 - LRB104 11424 BDA 21512 b
6332	6332	SB1442 - 176 - LRB104 11424 BDA 21512 b
6333	6333	1 anticipated tax credits, and any other direct
6334	6334	2 federal support.
6335	6335	3 The information described in this subparagraph (B) may
6336	6336	4 be submitted on a confidential basis and shall be treated
6337	6337	5 and maintained by the Agency, the procurement
6338	6338	6 administrator, and the Commission as confidential and
6339	6339	7 proprietary and exempt from disclosure under subparagraphs
6340	6340	8 (a) and (g) of paragraph (1) of Section 7 of the Freedom of
6341	6341	9 Information Act. The Office of the Attorney General shall
6342	6342	10 have access to, and maintain the confidentiality of, such
6343	6343	11 information pursuant to Section 6.5 of the Attorney
6344	6344	12 General Act.
6345	6345	13 (C) The Agency shall solicit bids for the contracts
6346	6346	14 described in this subsection (d-10) from carbon-free
6347	6347	15 energy resources that have satisfied the requirements of
6348	6348	16 subparagraph (B) of this paragraph (3). The contracts
6349	6349	17 procured pursuant to a procurement event shall reflect,
6350	6350	18 and be subject to, the following terms, requirements, and
6351	6351	19 limitations:
6352	6352	20 (i) Contracts are for delivery of carbon
6353	6353	21 mitigation credits, and are not energy or capacity
6354	6354	22 sales contracts requiring physical delivery. Pursuant
6355	6355	23 to item (iii), contract payments shall fully deduct
6356	6356	24 the value of any monetized federal production tax
6357	6357	25 credits, credits issued pursuant to a federal clean
6358	6358	26 energy standard, and other federal credits if
6359	6359
6360	6360
6361	6361
6362	6362
6363	6363
6364	6364	SB1442 - 176 - LRB104 11424 BDA 21512 b
6365	6365
6366	6366
6367	6367	SB1442- 177 -LRB104 11424 BDA 21512 b SB1442 - 177 - LRB104 11424 BDA 21512 b
6368	6368	SB1442 - 177 - LRB104 11424 BDA 21512 b
6369	6369	1 applicable.
6370	6370	2 (ii) Contracts for carbon mitigation credits shall
6371	6371	3 commence with the delivery year beginning on June 1,
6372	6372	4 2022 and shall be for a term of 5 delivery years
6373	6373	5 concluding on May 31, 2027.
6374	6374	6 (iii) The price per carbon mitigation credit to be
6375	6375	7 paid under a contract for a given delivery year shall
6376	6376	8 be equal to an accepted bid price less the sum of:
6377	6377	9 (I) one of the following energy price indices,
6378	6378	10 selected by the bidder at the time of the bid for
6379	6379	11 the term of the contract:
6380	6380	12 (aa) the weighted-average hourly day-ahead
6381	6381	13 price for the applicable delivery year at the
6382	6382	14 busbar of all resources procured pursuant to
6383	6383	15 this subsection (d-10), weighted by actual
6384	6384	16 production from the resources; or
6385	6385	17 (bb) the projected energy price for the
6386	6386	18 PJM Interconnection, LLC Northern Illinois Hub
6387	6387	19 for the applicable delivery year determined
6388	6388	20 according to subitem (aa) of item (iii) of
6389	6389	21 subparagraph (B) of paragraph (1) of
6390	6390	22 subsection (d-5).
6391	6391	23 (II) the Base Residual Auction Capacity Price
6392	6392	24 for the ComEd zone as determined by PJM
6393	6393	25 Interconnection, LLC, divided by 24 hours per day,
6394	6394	26 for the applicable delivery year for the first 3
6395	6395
6396	6396
6397	6397
6398	6398
6399	6399
6400	6400	SB1442 - 177 - LRB104 11424 BDA 21512 b
6401	6401
6402	6402
6403	6403	SB1442- 178 -LRB104 11424 BDA 21512 b SB1442 - 178 - LRB104 11424 BDA 21512 b
6404	6404	SB1442 - 178 - LRB104 11424 BDA 21512 b
6405	6405	1 delivery years, and then any subsequent delivery
6406	6406	2 years unless the PJM Interconnection, LLC applies
6407	6407	3 the Minimum Offer Price Rule to participating
6408	6408	4 carbon-free energy resources because they supply
6409	6409	5 carbon mitigation credits pursuant to this Section
6410	6410	6 at which time, upon notice by the carbon-free
6411	6411	7 energy resource to the Commission and subject to
6412	6412	8 the Commission's confirmation, the value under
6413	6413	9 this subitem shall be zero, as further described
6414	6414	10 in the carbon mitigation credit procurement plan;
6415	6415	11 and
6416	6416	12 (III) any value of monetized federal tax
6417	6417	13 credits, direct payments, or similar subsidy
6418	6418	14 provided to the carbon-free energy resource from
6419	6419	15 any unit of government that is not already
6420	6420	16 reflected in energy prices.
6421	6421	17 If the price-per-megawatt-hour calculation
6422	6422	18 performed under item (iii) of this subparagraph (C)
6423	6423	19 for a given delivery year results in a net positive
6424	6424	20 value, then the electric utility counterparty to the
6425	6425	21 contract shall multiply such net value by the
6426	6426	22 applicable contract quantity and remit the amount to
6427	6427	23 the supplier.
6428	6428	24 To protect retail customers from retail rate
6429	6429	25 impacts that may arise upon the initiation of carbon
6430	6430	26 policy changes, if the price-per-megawatt-hour
6431	6431
6432	6432
6433	6433
6434	6434
6435	6435
6436	6436	SB1442 - 178 - LRB104 11424 BDA 21512 b
6437	6437
6438	6438
6439	6439	SB1442- 179 -LRB104 11424 BDA 21512 b SB1442 - 179 - LRB104 11424 BDA 21512 b
6440	6440	SB1442 - 179 - LRB104 11424 BDA 21512 b
6441	6441	1 calculation performed under item (iii) of this
6442	6442	2 subparagraph (C) for a given delivery year results in
6443	6443	3 a net negative value, then the supplier counterparty
6444	6444	4 to the contract shall multiply such net value by the
6445	6445	5 applicable contract quantity and remit such amount to
6446	6446	6 the electric utility counterparty. The electric
6447	6447	7 utility shall reflect such amounts remitted by
6448	6448	8 suppliers as a credit on its retail customer bills as
6449	6449	9 soon as practicable.
6450	6450	10 (iv) To ensure that retail customers in Northern
6451	6451	11 Illinois do not pay more for carbon mitigation credits
6452	6452	12 than the value such credits provide, and
6453	6453	13 notwithstanding the provisions of this subsection
6454	6454	14 (d-10), the Agency shall not accept bids for contracts
6455	6455	15 that exceed a customer protection cap equal to the
6456	6456	16 baseline costs of carbon-free energy resources.
6457	6457	17 The baseline costs for the applicable year shall
6458	6458	18 be the following:
6459	6459	19 (I) For the delivery year beginning June 1,
6460	6460	20 2022, the baseline costs shall be an amount equal
6461	6461	21 to $30.30 per megawatt-hour.
6462	6462	22 (II) For the delivery year beginning June 1,
6463	6463	23 2023, the baseline costs shall be an amount equal
6464	6464	24 to $32.50 per megawatt-hour.
6465	6465	25 (III) For the delivery year beginning June 1,
6466	6466	26 2024, the baseline costs shall be an amount equal
6467	6467
6468	6468
6469	6469
6470	6470
6471	6471
6472	6472	SB1442 - 179 - LRB104 11424 BDA 21512 b
6473	6473
6474	6474
6475	6475	SB1442- 180 -LRB104 11424 BDA 21512 b SB1442 - 180 - LRB104 11424 BDA 21512 b
6476	6476	SB1442 - 180 - LRB104 11424 BDA 21512 b
6477	6477	1 to $33.43 per megawatt-hour.
6478	6478	2 (IV) For the delivery year beginning June 1,
6479	6479	3 2025, the baseline costs shall be an amount equal
6480	6480	4 to $33.50 per megawatt-hour.
6481	6481	5 (V) For the delivery year beginning June 1,
6482	6482	6 2026, the baseline costs shall be an amount equal
6483	6483	7 to $34.50 per megawatt-hour.
6484	6484	8 An Environmental Protection Agency consultant
6485	6485	9 forecast, included in a report issued April 14, 2021,
6486	6486	10 projects that a carbon-free energy resource has the
6487	6487	11 opportunity to earn on average approximately $30.28
6488	6488	12 per megawatt-hour, for the sale of energy and capacity
6489	6489	13 during the time period between 2022 and 2027.
6490	6490	14 Therefore, the sale of carbon mitigation credits
6491	6491	15 provides the opportunity to receive an additional
6492	6492	16 amount per megawatt-hour in addition to the projected
6493	6493	17 prices for energy and capacity.
6494	6494	18 Although actual energy and capacity prices may
6495	6495	19 vary from year-to-year, the General Assembly finds
6496	6496	20 that this customer protection cap will help ensure
6497	6497	21 that the cost of carbon mitigation credits will be
6498	6498	22 less than its value, based upon the social cost of
6499	6499	23 carbon identified in the Technical Support Document
6500	6500	24 issued in February 2021 by the U.S. Interagency
6501	6501	25 Working Group on Social Cost of Greenhouse Gases and
6502	6502	26 the PJM Interconnection, LLC carbon dioxide marginal
6503	6503
6504	6504
6505	6505
6506	6506
6507	6507
6508	6508	SB1442 - 180 - LRB104 11424 BDA 21512 b
6509	6509
6510	6510
6511	6511	SB1442- 181 -LRB104 11424 BDA 21512 b SB1442 - 181 - LRB104 11424 BDA 21512 b
6512	6512	SB1442 - 181 - LRB104 11424 BDA 21512 b
6513	6513	1 emission rate for 2020, and that a carbon-free energy
6514	6514	2 resource receiving payment for carbon mitigation
6515	6515	3 credits receives no more than necessary to keep those
6516	6516	4 units in operation.
6517	6517	5 (D) No later than 7 days after the effective date of
6518	6518	6 this amendatory Act of the 102nd General Assembly, the
6519	6519	7 Agency shall publish its proposed carbon mitigation credit
6520	6520	8 procurement plan. The Plan shall provide that winning bids
6521	6521	9 shall be selected by taking into consideration which
6522	6522	10 resources best match public interest criteria that
6523	6523	11 include, but are not limited to, minimizing carbon dioxide
6524	6524	12 emissions that result from electricity consumed in
6525	6525	13 Illinois and minimizing sulfur dioxide, nitrogen oxide,
6526	6526	14 and particulate matter emissions that adversely affect the
6527	6527	15 citizens of this State. The selection of winning bids
6528	6528	16 shall also take into account the incremental environmental
6529	6529	17 benefits resulting from the procurement or procurements,
6530	6530	18 such as any existing environmental benefits that are
6531	6531	19 preserved by a procurement held under this subsection
6532	6532	20 (d-10) and would cease to exist if the procurement were
6533	6533	21 not held, including the preservation of carbon-free energy
6534	6534	22 resources. For those bidders having the same public
6535	6535	23 interest criteria score, the relative ranking of such
6536	6536	24 bidders shall be determined by price. The Plan shall
6537	6537	25 describe in detail how each public interest factor shall
6538	6538	26 be considered and weighted in the bid selection process to
6539	6539
6540	6540
6541	6541
6542	6542
6543	6543
6544	6544	SB1442 - 181 - LRB104 11424 BDA 21512 b
6545	6545
6546	6546
6547	6547	SB1442- 182 -LRB104 11424 BDA 21512 b SB1442 - 182 - LRB104 11424 BDA 21512 b
6548	6548	SB1442 - 182 - LRB104 11424 BDA 21512 b
6549	6549	1 ensure that the public interest criteria are applied to
6550	6550	2 the procurement. The Plan shall, to the extent practical
6551	6551	3 and permissible by federal law, ensure that successful
6552	6552	4 bidders make commercially reasonable efforts to apply for
6553	6553	5 federal tax credits, direct payments, or similar subsidy
6554	6554	6 programs that support carbon-free generation and for which
6555	6555	7 the successful bidder is eligible. Upon publishing of the
6556	6556	8 carbon mitigation credit procurement plan, copies of the
6557	6557	9 plan shall be posted and made publicly available on the
6558	6558	10 Agency's website. All interested parties shall have 7 days
6559	6559	11 following the date of posting to provide comment to the
6560	6560	12 Agency on the plan. All comments shall be posted to the
6561	6561	13 Agency's website. Following the end of the comment period,
6562	6562	14 but no more than 19 days later than the effective date of
6563	6563	15 this amendatory Act of the 102nd General Assembly, the
6564	6564	16 Agency shall revise the plan as necessary based on the
6565	6565	17 comments received and file its carbon mitigation credit
6566	6566	18 procurement plan with the Commission.
6567	6567	19 (E) If the Commission determines that the plan is
6568	6568	20 likely to result in the procurement of cost-effective
6569	6569	21 carbon mitigation credits, then the Commission shall,
6570	6570	22 after notice and hearing and opportunity for comment, but
6571	6571	23 no later than 42 days after the Agency filed the plan,
6572	6572	24 approve the plan or approve it with modification. For
6573	6573	25 purposes of this subsection (d-10), "cost-effective" means
6574	6574	26 carbon mitigation credits that are procured from
6575	6575
6576	6576
6577	6577
6578	6578
6579	6579
6580	6580	SB1442 - 182 - LRB104 11424 BDA 21512 b
6581	6581
6582	6582
6583	6583	SB1442- 183 -LRB104 11424 BDA 21512 b SB1442 - 183 - LRB104 11424 BDA 21512 b
6584	6584	SB1442 - 183 - LRB104 11424 BDA 21512 b
6585	6585	1 carbon-free energy resources at prices that are within the
6586	6586	2 limits specified in this paragraph (3). As part of the
6587	6587	3 Commission's review and acceptance or rejection of the
6588	6588	4 procurement results, the Commission shall, in its public
6589	6589	5 notice of successful bidders:
6590	6590	6 (i) identify how the selected carbon-free energy
6591	6591	7 resources satisfy the public interest criteria
6592	6592	8 described in this paragraph (3) of minimizing carbon
6593	6593	9 dioxide emissions that result from electricity
6594	6594	10 consumed in Illinois and minimizing sulfur dioxide,
6595	6595	11 nitrogen oxide, and particulate matter emissions that
6596	6596	12 adversely affect the citizens of this State;
6597	6597	13 (ii) specifically address how the selection of
6598	6598	14 carbon-free energy resources takes into account the
6599	6599	15 incremental environmental benefits resulting from the
6600	6600	16 procurement, including any existing environmental
6601	6601	17 benefits that are preserved by the procurements held
6602	6602	18 under this amendatory Act of the 102nd General
6603	6603	19 Assembly and would have ceased to exist if the
6604	6604	20 procurements had not been held, such as the
6605	6605	21 preservation of carbon-free energy resources;
6606	6606	22 (iii) quantify the environmental benefit of
6607	6607	23 preserving the carbon-free energy resources procured
6608	6608	24 pursuant to this subsection (d-10), including the
6609	6609	25 following:
6610	6610	26 (I) an assessment value of avoided greenhouse
6611	6611
6612	6612
6613	6613
6614	6614
6615	6615
6616	6616	SB1442 - 183 - LRB104 11424 BDA 21512 b
6617	6617
6618	6618
6619	6619	SB1442- 184 -LRB104 11424 BDA 21512 b SB1442 - 184 - LRB104 11424 BDA 21512 b
6620	6620	SB1442 - 184 - LRB104 11424 BDA 21512 b
6621	6621	1 gas emissions measured as the product of the
6622	6622	2 carbon-free energy resources' output over the
6623	6623	3 contract term, using generally accepted
6624	6624	4 methodologies for the valuation of avoided
6625	6625	5 emissions; and
6626	6626	6 (II) an assessment of costs of replacement
6627	6627	7 with other carbon-free energy resources and
6628	6628	8 renewable energy resources, including wind and
6629	6629	9 photovoltaic generation, based upon an assessment
6630	6630	10 of the prices paid for renewable energy credits
6631	6631	11 through programs and procurements conducted
6632	6632	12 pursuant to subsection (c) of Section 1-75 of this
6633	6633	13 Act, and the additional storage necessary to
6634	6634	14 produce the same or similar capability of matching
6635	6635	15 customer usage patterns.
6636	6636	16 (F) The procurements described in this paragraph (3),
6637	6637	17 including, but not limited to, the execution of all
6638	6638	18 contracts procured, shall be completed no later than
6639	6639	19 December 3, 2021. The procurement and plan approval
6640	6640	20 processes required by this paragraph (3) shall be
6641	6641	21 conducted in conjunction with the procurement and plan
6642	6642	22 approval processes required by Section 16-111.5 of the
6643	6643	23 Public Utilities Act, to the extent practicable. However,
6644	6644	24 the Agency and Commission may, as appropriate, modify the
6645	6645	25 various dates and timelines under this subparagraph and
6646	6646	26 subparagraphs (D) and (E) of this paragraph (3) to meet
6647	6647
6648	6648
6649	6649
6650	6650
6651	6651
6652	6652	SB1442 - 184 - LRB104 11424 BDA 21512 b
6653	6653
6654	6654
6655	6655	SB1442- 185 -LRB104 11424 BDA 21512 b SB1442 - 185 - LRB104 11424 BDA 21512 b
6656	6656	SB1442 - 185 - LRB104 11424 BDA 21512 b
6657	6657	1 the December 3, 2021 contract execution deadline.
6658	6658	2 Following the completion of such procurements, and
6659	6659	3 consistent with this paragraph (3), the Agency shall
6660	6660	4 calculate the payments to be made under each contract in a
6661	6661	5 timely fashion.
6662	6662	6 (F-1) Costs incurred by the electric utility pursuant
6663	6663	7 to a contract authorized by this subsection (d-10) shall
6664	6664	8 be deemed prudently incurred and reasonable in amount, and
6665	6665	9 the electric utility shall be entitled to full cost
6666	6666	10 recovery pursuant to a tariff or tariffs filed with the
6667	6667	11 Commission.
6668	6668	12 (G) The counterparty electric utility shall retire all
6669	6669	13 carbon mitigation credits used to comply with the
6670	6670	14 requirements of this subsection (d-10).
6671	6671	15 (H) If a carbon-free energy resource is sold to
6672	6672	16 another owner, the rights, obligations, and commitments
6673	6673	17 under this subsection (d-10) shall continue to the
6674	6674	18 subsequent owner.
6675	6675	19 (I) This subsection (d-10) shall become inoperative on
6676	6676	20 January 1, 2028.
6677	6677	21 (e) The draft procurement plans are subject to public
6678	6678	22 comment, as required by Section 16-111.5 of the Public
6679	6679	23 Utilities Act.
6680	6680	24 (f) The Agency shall submit the final procurement plan to
6681	6681	25 the Commission. The Agency shall revise a procurement plan if
6682	6682	26 the Commission determines that it does not meet the standards
6683	6683
6684	6684
6685	6685
6686	6686
6687	6687
6688	6688	SB1442 - 185 - LRB104 11424 BDA 21512 b
6689	6689
6690	6690
6691	6691	SB1442- 186 -LRB104 11424 BDA 21512 b SB1442 - 186 - LRB104 11424 BDA 21512 b
6692	6692	SB1442 - 186 - LRB104 11424 BDA 21512 b
6693	6693	1 set forth in Section 16-111.5 of the Public Utilities Act.
6694	6694	2 (g) The Agency shall assess fees to each affected utility
6695	6695	3 to recover the costs incurred in preparation of the annual
6696	6696	4 procurement plan for the utility.
6697	6697	5 (h) The Agency shall assess fees to each bidder to recover
6698	6698	6 the costs incurred in connection with a competitive
6699	6699	7 procurement process.
6700	6700	8 (i) A renewable energy credit, carbon emission credit,
6701	6701	9 zero emission credit, or carbon mitigation credit can only be
6702	6702	10 used once to comply with a single portfolio or other standard
6703	6703	11 as set forth in subsection (c), subsection (d), or subsection
6704	6704	12 (d-5) of this Section, respectively. A renewable energy
6705	6705	13 credit, carbon emission credit, zero emission credit, or
6706	6706	14 carbon mitigation credit cannot be used to satisfy the
6707	6707	15 requirements of more than one standard. If more than one type
6708	6708	16 of credit is issued for the same megawatt hour of energy, only
6709	6709	17 one credit can be used to satisfy the requirements of a single
6710	6710	18 standard. After such use, the credit must be retired together
6711	6711	19 with any other credits issued for the same megawatt hour of
6712	6712	20 energy.
6713	6713	21 (Source: P.A. 102-662, eff. 9-15-21; 103-380, eff. 1-1-24;
6714	6714	22 103-580, eff. 12-8-23.)
6715	6715	23 Section 105. The State Finance Act is amended by adding
6716	6716	24 Section 5.1030 as follows:
6717	6717
6718	6718
6719	6719
6720	6720
6721	6721
6722	6722	SB1442 - 186 - LRB104 11424 BDA 21512 b
6723	6723
6724	6724
6725	6725	SB1442- 187 -LRB104 11424 BDA 21512 b SB1442 - 187 - LRB104 11424 BDA 21512 b
6726	6726	SB1442 - 187 - LRB104 11424 BDA 21512 b
6727	6727	1 (30 ILCS 105/5.1030 new)
6728	6728	2 Sec. 5.1030. The Illinois Rust Belt to Green Belt Fund.
6729	6729
6730	6730
6731	6731
6732	6732
6733	6733
6734	6734	SB1442 - 187 - LRB104 11424 BDA 21512 b