Illinois 2023-2024 Regular Session

Illinois House Bill HB5021 Compare Versions

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

Old	New	Differences
1	1	103RD GENERAL ASSEMBLY State of Illinois 2023 and 2024 HB5021 Introduced , by Rep. Janet Yang Rohr SYNOPSIS AS INTRODUCED: See Index Creates the Municipal and Cooperative Electric Utility Planning and Transparency Act. Sets forth legislative findings and objectives. Provides that beginning on November 1, 2024, and every 3 years thereafter on November 1, all electric cooperatives with members in the State, municipal power agencies, and municipalities shall file with the Illinois Power Agency an integrated resource plan. Includes provisions regarding the purposes and available resources for the integrated resource plan and rulemaking powers of the Agency. Requires the Agency to maintain a list of qualified experts or expert consulting firms for the purpose of developing integrated resource plans. Sets forth meeting requirements for an electric cooperative and publishing and posting requirements for specific information related to an electric cooperative. Amends the Open Meetings Act. Provides that a public body may hold closed meetings to consider the operation by a municipality of a municipal utility or the operation of a municipal power agency or municipal natural gas agency when the discussion involves certain topics. Amends the Illinois Municipal Code. Allows any additional municipality which operates an electric utility system to join a municipal power agency consistent with the bylaws of the municipal power agency, and upon payment of any termination obligations. Outlines a number of requirements for a municipal power agency. Makes other changes. Amends the Public Utilities Act. In a provision regarding net electricity metering, defines "electricity provider" and "electric utility". Makes other changes. Amends the Eminent Domain Act. Provides that for all acquisitions where the property, or any right or interest in property, is to be used for utility purposes, and where the condemning authority is an entity required to submit an integrated resource plan under the Municipal and Cooperative Electric Utility Planning and Transparency Act, the rebuttable presumption that such acquisition of that property is primarily for the benefit, use, or enjoyment of the public and necessary for a public purpose shall only apply if the most recent integrated resource plan filed by the condemning authority identified the facility or articulated a need for a facility similar capacity and type to the facility for which the property or right or interest is sought. Effective immediately. LRB103 36729 LNS 66839 b A BILL FOR 103RD GENERAL ASSEMBLY State of Illinois 2023 and 2024 HB5021 Introduced , by Rep. Janet Yang Rohr SYNOPSIS AS INTRODUCED: See Index See Index Creates the Municipal and Cooperative Electric Utility Planning and Transparency Act. Sets forth legislative findings and objectives. Provides that beginning on November 1, 2024, and every 3 years thereafter on November 1, all electric cooperatives with members in the State, municipal power agencies, and municipalities shall file with the Illinois Power Agency an integrated resource plan. Includes provisions regarding the purposes and available resources for the integrated resource plan and rulemaking powers of the Agency. Requires the Agency to maintain a list of qualified experts or expert consulting firms for the purpose of developing integrated resource plans. Sets forth meeting requirements for an electric cooperative and publishing and posting requirements for specific information related to an electric cooperative. Amends the Open Meetings Act. Provides that a public body may hold closed meetings to consider the operation by a municipality of a municipal utility or the operation of a municipal power agency or municipal natural gas agency when the discussion involves certain topics. Amends the Illinois Municipal Code. Allows any additional municipality which operates an electric utility system to join a municipal power agency consistent with the bylaws of the municipal power agency, and upon payment of any termination obligations. Outlines a number of requirements for a municipal power agency. Makes other changes. Amends the Public Utilities Act. In a provision regarding net electricity metering, defines "electricity provider" and "electric utility". Makes other changes. Amends the Eminent Domain Act. Provides that for all acquisitions where the property, or any right or interest in property, is to be used for utility purposes, and where the condemning authority is an entity required to submit an integrated resource plan under the Municipal and Cooperative Electric Utility Planning and Transparency Act, the rebuttable presumption that such acquisition of that property is primarily for the benefit, use, or enjoyment of the public and necessary for a public purpose shall only apply if the most recent integrated resource plan filed by the condemning authority identified the facility or articulated a need for a facility similar capacity and type to the facility for which the property or right or interest is sought. Effective immediately. LRB103 36729 LNS 66839 b LRB103 36729 LNS 66839 b A BILL FOR
2	2	103RD GENERAL ASSEMBLY State of Illinois 2023 and 2024 HB5021 Introduced , by Rep. Janet Yang Rohr SYNOPSIS AS INTRODUCED:
3	3	See Index See Index
4	4	See Index
5	5	Creates the Municipal and Cooperative Electric Utility Planning and Transparency Act. Sets forth legislative findings and objectives. Provides that beginning on November 1, 2024, and every 3 years thereafter on November 1, all electric cooperatives with members in the State, municipal power agencies, and municipalities shall file with the Illinois Power Agency an integrated resource plan. Includes provisions regarding the purposes and available resources for the integrated resource plan and rulemaking powers of the Agency. Requires the Agency to maintain a list of qualified experts or expert consulting firms for the purpose of developing integrated resource plans. Sets forth meeting requirements for an electric cooperative and publishing and posting requirements for specific information related to an electric cooperative. Amends the Open Meetings Act. Provides that a public body may hold closed meetings to consider the operation by a municipality of a municipal utility or the operation of a municipal power agency or municipal natural gas agency when the discussion involves certain topics. Amends the Illinois Municipal Code. Allows any additional municipality which operates an electric utility system to join a municipal power agency consistent with the bylaws of the municipal power agency, and upon payment of any termination obligations. Outlines a number of requirements for a municipal power agency. Makes other changes. Amends the Public Utilities Act. In a provision regarding net electricity metering, defines "electricity provider" and "electric utility". Makes other changes. Amends the Eminent Domain Act. Provides that for all acquisitions where the property, or any right or interest in property, is to be used for utility purposes, and where the condemning authority is an entity required to submit an integrated resource plan under the Municipal and Cooperative Electric Utility Planning and Transparency Act, the rebuttable presumption that such acquisition of that property is primarily for the benefit, use, or enjoyment of the public and necessary for a public purpose shall only apply if the most recent integrated resource plan filed by the condemning authority identified the facility or articulated a need for a facility similar capacity and type to the facility for which the property or right or interest is sought. Effective immediately.
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11	11	1 AN ACT concerning regulation.
12	12	2 Be it enacted by the People of the State of Illinois,
13	13	3 represented in the General Assembly:
14	14	4 Section 1. Short title. This Act may be cited as the
15	15	5 Municipal and Cooperative Electric Utility Planning and
16	16	6 Transparency Act.
17	17	7 Section 5. Legislative findings and objectives. The
18	18	8 General Assembly finds:
19	19	9 (1) Municipal and cooperative electric utilities
20	20	10 provide electricity to more than 1,000,000 State
21	21	11 residents.
22	22	12 (2) These utilities are managed by elected officials,
23	23	13 elected board members, or their appointees. Due to their
24	24	14 governance structures, municipal and cooperative electric
25	25	15 utilities are exempt from certain regulatory requirements
26	26	16 and oversight under State and federal law.
27	27	17 (3) State residents who are served by these utilities,
28	28	18 and who pay rates for electricity set by these utilities,
29	29	19 often lack access to important information about these
30	30	20 utilities' generation portfolios, procurement, management
31	31	21 practices, and budgets. Because democratic elections by
32	32	22 member-ratepayers or customers are the ultimate guarantor
33	33	23 of the integrity and cost-effectiveness of these
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37	37	103RD GENERAL ASSEMBLY State of Illinois 2023 and 2024 HB5021 Introduced , by Rep. Janet Yang Rohr SYNOPSIS AS INTRODUCED:
38	38	See Index See Index
39	39	See Index
40	40	Creates the Municipal and Cooperative Electric Utility Planning and Transparency Act. Sets forth legislative findings and objectives. Provides that beginning on November 1, 2024, and every 3 years thereafter on November 1, all electric cooperatives with members in the State, municipal power agencies, and municipalities shall file with the Illinois Power Agency an integrated resource plan. Includes provisions regarding the purposes and available resources for the integrated resource plan and rulemaking powers of the Agency. Requires the Agency to maintain a list of qualified experts or expert consulting firms for the purpose of developing integrated resource plans. Sets forth meeting requirements for an electric cooperative and publishing and posting requirements for specific information related to an electric cooperative. Amends the Open Meetings Act. Provides that a public body may hold closed meetings to consider the operation by a municipality of a municipal utility or the operation of a municipal power agency or municipal natural gas agency when the discussion involves certain topics. Amends the Illinois Municipal Code. Allows any additional municipality which operates an electric utility system to join a municipal power agency consistent with the bylaws of the municipal power agency, and upon payment of any termination obligations. Outlines a number of requirements for a municipal power agency. Makes other changes. Amends the Public Utilities Act. In a provision regarding net electricity metering, defines "electricity provider" and "electric utility". Makes other changes. Amends the Eminent Domain Act. Provides that for all acquisitions where the property, or any right or interest in property, is to be used for utility purposes, and where the condemning authority is an entity required to submit an integrated resource plan under the Municipal and Cooperative Electric Utility Planning and Transparency Act, the rebuttable presumption that such acquisition of that property is primarily for the benefit, use, or enjoyment of the public and necessary for a public purpose shall only apply if the most recent integrated resource plan filed by the condemning authority identified the facility or articulated a need for a facility similar capacity and type to the facility for which the property or right or interest is sought. Effective immediately.
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43	43	A BILL FOR
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68	68	1 utilities' operations, access to this information is
69	69	2 crucial to ensuring management of these utilities is
70	70	3 prudent and responsive.
71	71	4 (4) Good utility practice entails long-term planning
72	72	5 on the part of a utility, including anticipating
73	73	6 retirement of existing generation resources, planning new
74	74	7 generation build or purchase well in advance of any
75	75	8 capacity shortfall, and developing rigorous estimates of
76	76	9 future load to inform procurement, construction, and
77	77	10 retirement decisions.
78	78	11 (5) In many other states, integrated resource planning
79	79	12 processes have been used to avoid capacity shortfalls,
80	80	13 minimize ratepayer costs, and increase public
81	81	14 participation in and knowledge of electric generation
82	82	15 portfolio choices, even where the planning utility is not
83	83	16 otherwise subject to rate approval by the state.
84	84	17 (6) It is in the best interests of State electricity
85	85	18 customers and member-ratepayers that electricity is
86	86	19 provided by a portfolio of generation and storage
87	87	20 resources and demand-side programs that minimizes both
88	88	21 cost and environmental impacts and that long-term utility
89	89	22 planning can and should facilitate the achievement of such
90	90	23 portfolios.
91	91	24 (7) With the enactment of the Inflation Reduction Act
92	92	25 of 2022, municipal and cooperative electric utilities have
93	93	26 access to a variety of federal funding streams designed to
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104	104	1 facilitate transition from fossil fuel to renewable
105	105	2 generation. Consistent with Congress's intent, municipal
106	106	3 and cooperative electric utilities should perform a
107	107	4 comprehensive analysis of their existing portfolio and
108	108	5 have a duty, as utility managers, to identify
109	109	6 opportunities to minimize member-ratepayer and customer
110	110	7 costs.
111	111	8 (8) To ensure utilities minimize ratepayer costs,
112	112	9 maximize opportunities for transition from fossil fuels to
113	113	10 renewable resources, and to increase transparency and
114	114	11 democratic participation, it is important that municipal
115	115	12 and cooperative electric utilities participate in an
116	116	13 integrated resource planning process with public
117	117	14 participation and Illinois Power Agency oversight.
118	118	15 Section 10. Definitions. As used in this Act:
119	119	16 "Agency" means the Illinois Power Agency.
120	120	17 "Demand-side program" means a program implemented by or on
121	121	18 behalf of a utility to reduce retail customer consumption
122	122	19 (MWh) or shift the time of consumption of energy (MW) from end
123	123	20 users, including energy efficiency programs, demand response
124	124	21 programs, and programs for the promotion or aggregation of
125	125	22 distributed generation.
126	126	23 "Electric cooperative" has the meaning given to that term
127	127	24 in Section 3-119 of the Public Utilities Act.
128	128	25 "Generation resource" means a facility for the generation
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139	139	1 of electricity.
140	140	2 "Municipal power agency" has the meaning given to that
141	141	3 term in Section 11-119.1-3 of the Illinois Municipal Code.
142	142	4 "Municipality" has the meaning given to that term in
143	143	5 Section 11-119.1-3 of the Illinois Municipal Code.
144	144	6 "Renewable generation resource" means a resource for
145	145	7 generating electricity that uses wind, solar, or geothermal
146	146	8 energy.
147	147	9 "Storage resource" means a commercially available
148	148	10 technology that uses mechanical, chemical, or thermal
149	149	11 processes to store energy and deliver the stored energy as
150	150	12 electricity for use at a later time and is capable of being
151	151	13 controlled by the distribution or transmission entity managing
152	152	14 it, to enable and optimize the safe and reliable operation of
153	153	15 the electric system.
154	154	16 "Utility" means a municipal power agency, municipality, or
155	155	17 electric cooperative.
156	156	18 Section 15. Purpose and contents of integrated resource
157	157	19 plan.
158	158	20 (a) Beginning on November 1, 2024, and every 3 years
159	159	21 thereafter on November 1, all electric cooperatives with
160	160	22 members in this State, municipal power agencies, and
161	161	23 municipalities shall file with the Agency an integrated
162	162	24 resource plan, except that municipalities and electric
163	163	25 cooperatives that are members of, and have a full requirements
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174	174	1 contract with, a municipal power agency or electric
175	175	2 cooperative subject to this Act may file a statement adopting
176	176	3 such other utility's integrated resource plan.
177	177	4 (b) The purposes of the integrated resource plan are to
178	178	5 provide a comprehensive description of the utility's current
179	179	6 portfolio of electrical generation, storage, demand-side
180	180	7 programs, and transmission resources, to forecast future load
181	181	8 changes to facilitate prudent planning with respect to
182	182	9 resource procurement and retirement, to determine what
183	183	10 resource portfolio will meet ratepayers' needs while
184	184	11 minimizing cost and environmental impact, and to articulate
185	185	12 steps the utility will take to reduce customer costs and
186	186	13 environmental impacts through changes to its current
187	187	14 generation portfolio through construction, procurement,
188	188	15 retirement, or demand-side programs.
189	189	16 (c) As part of the integrated resource plan development
190	190	17 process, a utility shall consider all resources reasonably
191	191	18 available or reasonably likely to be available during the
192	192	19 relevant time period to satisfy the demand for electricity
193	193	20 services for a 20-year planning period, taking into account
194	194	21 both supply-side and demand-side electric power resources.
195	195	22 (d) An integrated resource plan shall include, at a
196	196	23 minimum:
197	197	24 (1) A list of all electricity generation facilities
198	198	25 owned by the utility, in whole or in part. For each such
199	199	26 facility, the integrated resource plan shall report:
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210	210	1 (A) general location;
211	211	2 (B) ownership information, if ownership is shared
212	212	3 with another entity;
213	213	4 (C) type of fuel;
214	214	5 (D) the date of commercial operation;
215	215	6 (E) expected useful life;
216	216	7 (F) expected retirement date for any resource
217	217	8 expected to retire within the next 10 years, and an
218	218	9 explanation of the reason for the retirement;
219	219	10 (G) nameplate and peak available capacity;
220	220	11 (H) total MWh generated at the facility during the
221	221	12 previous calendar year;
222	222	13 (I) the date on which the facility is anticipated
223	223	14 to be fully depreciated; and
224	224	15 (J) any compliance obligations, or compliance
225	225	16 obligations expected to apply within the next 10
226	226	17 years, and any proposed or anticipated expenditures
227	227	18 intended to meet those obligations.
228	228	19 (2) A list of all power purchase agreements to which
229	229	20 the utility is a party, whether as purchaser or seller,
230	230	21 including the counterparty, general location and type of
231	231	22 generation resource providing power per the agreement,
232	232	23 date on which the agreement was entered into, duration of
233	233	24 the agreement, and the energy and capacity terms of the
234	234	25 agreement.
235	235	26 (3) A list of any sale transactions of any energy or
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246	246	1 capacity to any purchaser.
247	247	2 (4) A list of any demand-side programs and total
248	248	3 distributed generation.
249	249	4 (5) A narrative description of all existing
250	250	5 transmission facilities owned by the utility, in whole or
251	251	6 in part, that identifies any transmission constraints or
252	252	7 critical contingencies, and identification of the regional
253	253	8 transmission organization, if any, which exercises
254	254	9 operational control over the transmission facility.
255	255	10 (6) A list of all capital expenditures exceeding
256	256	11 $1,000,000 in the previous calendar year that includes a
257	257	12 brief description of the expenditure, the total amount
258	258	13 expended, and whether the expenditure was required to
259	259	14 conform with State or federal law, rule, or regulation;
260	260	15 (7) A description of all transmission costs,
261	261	16 disaggregated by expenditure, that identifies all capital
262	262	17 expenditures on physical infrastructure and contracts for
263	263	18 rights costing greater than $1,000,000 over the term of
264	264	19 the agreement.
265	265	20 (8) A copy of the most recent FERC Form 1 filed by the
266	266	21 utility. If no such FERC Form 1 has been filed, the utility
267	267	22 shall complete a FERC Form 1 for the prior calendar year.
268	268	23 (9) A range of load forecasts for the 5-year planning
269	269	24 period that includes hourly data representing a high-load,
270	270	25 low-load, and expected-load scenario for all retail
271	271	26 customers, consistent with the requirements of paragraph
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282	282	1 (1) of subsection (d) of Section 16-111.5 of the Public
283	283	2 Utilities Act and any associated rules or regulations.
284	284	3 Such forecasts shall include:
285	285	4 (A) all underlying assumptions;
286	286	5 (B) an hourly load analysis consistent with the
287	287	6 requirements of paragraph (1) of subsection (b) of
288	288	7 Section 16-111.5 of the Public Utilities Act;
289	289	8 (C) analysis of the impact of any demand-side
290	290	9 programs, consistent with paragraph (2) of subsection
291	291	10 (b) of Section 16-111.5 of the Public Utilities Act;
292	292	11 (D) any reserve margin or other obligations placed
293	293	12 on the utility by regional transmission organizations
294	294	13 to which it is a member; and
295	295	14 (E) to the extent the information is available, an
296	296	15 assessment of the accuracy of any past load forecasts
297	297	16 submitted pursuant to this Section and an explanation
298	298	17 of any deviation of greater than 10% in either
299	299	18 direction from the forecasted load.
300	300	19 (10) The results of an all-source request for
301	301	20 proposals for generation resources and capacity contracts.
302	302	21 (11) A 5-year action plan for meeting the forecasted
303	303	22 load that minimizes customer cost and adverse
304	304	23 environmental impacts. As part of the action plan, the
305	305	24 utility shall:
306	306	25 (A) Identify any generation or storage resources
307	307	26 anticipated to be removed from service in the 5 years
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318	318	1 following the date on which the integrated resource
319	319	2 plan is submitted.
320	320	3 (B) Determine whether given forecasted load growth
321	321	4 or unit retirements, or both, the utility will need to
322	322	5 procure additional capacity and energy, and provide a
323	323	6 quantitative estimate of any such gap between
324	324	7 forecasted load and supply-side resources.
325	325	8 (C) Provide a narrative description of the
326	326	9 utility's process for evaluating possible resources to
327	327	10 secure this additional capacity and energy.
328	328	11 (D) Provide a narrative description of the
329	329	12 utility's processes for assessing the present economic
330	330	13 value of existing generation and state whether,
331	331	14 consistent with this methodology, any currently
332	332	15 operating units, if any, could be replaced by other
333	333	16 resources at lower cost to ratepayers.
334	334	17 (E) Identify a preferred portfolio of generation,
335	335	18 storage, and demand-side programs that, in the
336	336	19 utility's judgment, meets its forecasted load while
337	337	20 minimizing the ratepayer cost and environmental
338	338	21 impacts to the extent reasonably achievable in the 5
339	339	22 years covered by the action plan. The portfolio shall
340	340	23 incorporate any capacity or other reliability
341	341	24 requirements of any regional transmission organization
342	342	25 of which the utility is a member.
343	343	26 (F) If the preferred portfolio includes the
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354	354	1 construction of new generation or storage resources or
355	355	2 transmission facilities, identify the preferred site
356	356	3 for all new construction of generation, storage, or
357	357	4 transmission facilities.
358	358	5 (G) If the utility states that it intends to
359	359	6 remove a generation resource from service, include in
360	360	7 the integrated resource plan a statement describing
361	361	8 the utility's plan to minimize economic impacts to
362	362	9 workers due to facility retirement. This statement
363	363	10 shall include a description of:
364	364	11 (i) the utility's efforts to collaborate with
365	365	12 the workers and their designated representatives,
366	366	13 if any;
367	367	14 (ii) a transition timeline or date certain on
368	368	15 which such a transition timeline shall be made
369	369	16 available to ensure certainty for workers;
370	370	17 (iii) the utility's efforts to protect pension
371	371	18 benefits and extend or replace health insurance,
372	372	19 life insurance, and other employment benefits;
373	373	20 (iv) all training and skill development
374	374	21 programs to be made available for workers who will
375	375	22 see their employment reduced or eliminated as a
376	376	23 result of the retirement; and
377	377	24 (v) any agreements with local governments
378	378	25 regarding continuing tax or other transfer
379	379	26 payments following the facility's retirement
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390	390	1 intended to minimize the impact on local services.
391	391	2 (H) Describe any anticipated capital expenditures
392	392	3 in excess of $1,000,000 at existing generation
393	393	4 facilities and the reason for such expenditures.
394	394	5 (12) A description of all models and methodologies
395	395	6 used in performing the integrated resource planning
396	396	7 process. The utility shall provide to the Agency, upon
397	397	8 request, reasonable access to any computer models used in
398	398	9 the analysis and workpapers, in electronic form, relied on
399	399	10 in preparation of the report.
400	400	11 (e) As part of all integrated resource plans submitted in
401	401	12 2024, the utility shall identify all programs, grants, loans,
402	402	13 or tax benefits for which the utility is eligible pursuant to
403	403	14 the Inflation Reduction Act of 2022, and state whether the
404	404	15 utility has applied for or otherwise used the program, grant,
405	405	16 loan, or tax benefit. If the utility has not yet applied for or
406	406	17 utilized the benefit, the utility shall state whether it
407	407	18 intends to do so.
408	408	19 (f) Each utility shall submit, as part of its integrated
409	409	20 resource plan, a least cost plan for constructing or procuring
410	410	21 renewable energy resources to meet a minimum percentage of its
411	411	22 load for all retail customers as follows: 25% by June 1, 2026,
412	412	23 increasing by at least 3% each delivery year thereafter to at
413	413	24 least 40% by the 2030 delivery year, and continuing at no less
414	414	25 than 40% for each delivery year thereafter.
415	415	26 (g) Beginning in 2031, each utility shall submit, as part
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426	426	1 of its integrated resource plan, a least cost plan for
427	427	2 supplying 100% of its total projected load through renewable
428	428	3 generation resources in combination with storage resources and
429	429	4 demand-side programs by 2045. This least cost plan shall
430	430	5 provide for the retirement of all coal and gas generation
431	431	6 resources by January 1, 2045.
432	432	7 (h) The Agency may adopt rules establishing additional
433	433	8 requirements as to the form and content of integrated resource
434	434	9 plans, including, but not limited to, specifying forecast
435	435	10 methodologies.
436	436	11 Section 20. Stakeholder process. Prior to the submission
437	437	12 of an integrated resource plan, a municipality, municipal
438	438	13 power agency, or electric cooperative required to submit an
439	439	14 integrated resource plan shall hold at least 2 stakeholders
440	440	15 meetings open to all ratepayers and members of the public.
441	441	16 Notice of the meetings shall be sent to all customers not less
442	442	17 than 30 days prior to the meeting. During the meetings the
443	443	18 utility shall describe its processes for developing the
444	444	19 integrated resource plan and its core assumptions and
445	445	20 constraints, present its proposed preferred portfolio, and
446	446	21 describe any planned retirements, capital expenditures on
447	447	22 existing generation resources likely to exceed $1,000,000, and
448	448	23 planned construction. Each meeting shall allow time for public
449	449	24 comment and the utility shall provide attendees with a means
450	450	25 of providing public comment in writing following the meeting.
451	451
452	452
453	453
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461	461	1 Section 25. Procedures for submission of integrated
462	462	2 resource plan.
463	463	3 (a) Each municipality, municipal power agency, and
464	464	4 electric cooperative shall submit its integrated resource
465	465	5 plan, as set forth in this Act, to the Agency by October 1 of
466	466	6 the calendar year.
467	467	7 (b) The Agency may request further information from the
468	468	8 utility. Any such requests shall be made in writing. If the
469	469	9 Agency requests additional information, the utility shall
470	470	10 provide responses no later than 15 days following the request.
471	471	11 (c) The Agency shall facilitate public comment on the
472	472	12 integrated resource plan, as follows:
473	473	13 (1) upon submission of the integrated resource plan,
474	474	14 the Agency shall post the integrated resource plan
475	475	15 publicly on its website. The plan shall remain publicly
476	476	16 accessible for at least 60 days.
477	477	17 (2) the utility shall hold at least 2 public meetings,
478	478	18 one in person and one remotely, where it shall make a
479	479	19 representative available to address questions about the
480	480	20 resource plan. The meetings shall be held no sooner than
481	481	21 15 days, and no later than 45 days, after the integrated
482	482	22 resource plan is made available to the public.
483	483	23 (3) the Agency shall accept public comments on the
484	484	24 integrated resource plan for 60 days following its public
485	485	25 posting via website, email, or mail. The Agency may extend
486	486
487	487
488	488
489	489
490	490
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492	492
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496	496	1 this public comment period by an additional 60 days upon
497	497	2 request by members of the public; and
498	498	3 (4) after the conclusion of the public comment period,
499	499	4 as determined by the Agency, the Agency shall transmit
500	500	5 copies of all public comments received to the utility.
501	501	6 (d) The utility shall review public comments and provide
502	502	7 responses that reasonably address all issues or questions
503	503	8 raised by such comments. The utility may modify its integrated
504	504	9 resource plan in response to these comments. The utility shall
505	505	10 prepare a document with responses to public comments and
506	506	11 submit this response document to the Agency no later than 90
507	507	12 days after receiving the comments from the agency. This
508	508	13 response document shall be posted publicly on the Agency's
509	509	14 website along with the original integrated resource plan, as
510	510	15 submitted, and any revisions made by the utility in response
511	511	16 to public comments.
512	512	17 (e) The Agency shall maintain public access to all
513	513	18 integrated resource plans submitted pursuant to this Act,
514	514	19 accessible through the Agency's website, for no less than 10
515	515	20 years following each integrated resource plan's initial
516	516	21 submission.
517	517	22 Section 30. Use of independent expert.
518	518	23 (a) The Agency shall maintain a list of qualified experts
519	519	24 or expert consulting firms for the purpose of developing
520	520	25 integrated resource plans on behalf of municipalities,
521	521
522	522
523	523
524	524
525	525
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531	531	1 municipal power agencies, and cooperatives. In order to
532	532	2 qualify an expert or expert consulting firm must have:
533	533	3 (1) direct previous experience assembling power supply
534	534	4 plans or portfolios for utilities;
535	535	5 (2) an advanced degree in economics, mathematics,
536	536	6 engineering, risk management, or a related area of study;
537	537	7 (3) 10 years of experience in the electricity sector;
538	538	8 (4) expertise in wholesale electricity market rules,
539	539	9 including those established by the federal Energy
540	540	10 Regulatory Commission and regional transmission
541	541	11 organizations; and
542	542	12 (5) adequate resources to perform and fulfill the
543	543	13 required functions and responsibilities.
544	544	14 (b) The Agency may assemble the list as part of the process
545	545	15 for developing a list of qualified experts for experts to
546	546	16 develop procurement plans, as set forth in subsection (a) of
547	547	17 Section 1-75 of the Illinois Power Agency Act.
548	548	18 (c) The Agency shall provide affected utilities and other
549	549	19 interested parties with the lists of qualified experts or
550	550	20 expert consulting firms identified through the request for
551	551	21 qualifications processes that are under consideration to
552	552	22 prepare the integrated resource plan on behalf of the utility.
553	553	23 The Agency shall also provide each qualified expert's or
554	554	24 expert consulting firm's response to the request for
555	555	25 qualifications. A utility shall, within 5 business days,
556	556	26 notify the Agency in writing if it objects to any experts or
557	557
558	558
559	559
560	560
561	561
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567	567	1 expert consulting firms on the lists. Objections shall be
568	568	2 based on:
569	569	3 (1) the failure to satisfy qualification criteria;
570	570	4 (2) the identification of a conflict of interest; or
571	571	5 (3) the evidence of inappropriate bias for or against
572	572	6 potential bidders or the affected utilities.
573	573	7 The Agency shall remove experts or expert consulting firms
574	574	8 from the lists within 10 days if there is a reasonable basis
575	575	9 for an objection and provide the updated lists to the affected
576	576	10 utilities and other interested parties. If the Agency fails to
577	577	11 remove an expert or expert consulting firm from the list, the
578	578	12 objecting utility may withdraw its application and develop its
579	579	13 integrated resource plan without agency assistance.
580	580	14 (d) A utility required to submit an integrated resource
581	581	15 plan may elect to rely on an expert or expert consulting firm
582	582	16 selected by the Agency to develop the plan and conduct
583	583	17 stakeholder processes.
584	584	18 (e) A utility may submit a request to the Agency, not less
585	585	19 than 6 months prior to the date on which the integrated
586	586	20 resource plan is due, for such an expert or expert consulting
587	587	21 firm.
588	588	22 (f) Upon receipt of such a request, the Agency shall issue
589	589	23 requests for proposals to the qualified experts on the list
590	590	24 assembled as set forth in subsections (a) through (c) to
591	591	25 develop an integrated resource plan for that utility. The
592	592	26 Agency shall select an expert or expert consulting firm to
593	593
594	594
595	595
596	596
597	597
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599	599
600	600
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603	603	1 develop the integrated resource plan on behalf of the utility
604	604	2 based on the proposals submitted.
605	605	3 (g) Subject to appropriation, if a utility elects to rely
606	606	4 on an expert or expert consulting firm selected by the Agency,
607	607	5 90% of the costs assessed by the expert for development of the
608	608	6 integrated resource plan shall be paid by the Agency, up to
609	609	7 $250,000, and the remainder paid by the utility.
610	610	8 Section 35. Electric cooperatives member access.
611	611	9 (a) As used in this Section, "meeting" has the meaning
612	612	10 given to that term in Section 1.02 of the Open Meetings Act.
613	613	11 (b) As used in this Section, except for subsection (j),
614	614	12 "member" includes all members of an electric cooperative in
615	615	13 accordance with the cooperative's bylaws. Where a generation
616	616	14 and transmission electric cooperative's members are electric
617	617	15 cooperatives rather than individuals, members of those
618	618	16 member-cooperatives are members of the generation and
619	619	17 transmission electric cooperative for purposes of this
620	620	18 Section. As used in subsection (j), "member" includes only
621	621	19 members of an electric cooperative with individual members.
622	622	20 (c) All meetings of an electric cooperative shall be open
623	623	21 to all members, except that a cooperative, by a two-thirds
624	624	22 affirmative vote of the board members present, may go into
625	625	23 executive session for consideration of documents or
626	626	24 information deemed to be confidential for legal, commercial,
627	627	25 or personnel purposes.
628	628
629	629
630	630
631	631
632	632
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634	634
635	635
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638	638	1 (1) Before a board of directors convenes in executive
639	639	2 session, the board shall announce the general topic of the
640	640	3 executive session.
641	641	4 (2) Notice of all meetings of an electric cooperative
642	642	5 shall be posted on the website of the electric cooperative
643	643	6 at least 15 days prior to the meeting. Minutes of all
644	644	7 meetings of an electric cooperative shall be posted on the
645	645	8 website of the electric cooperative as soon as they have
646	646	9 been approved and shall remain posted for at least one
647	647	10 year after the date of the meeting. Upon request of a
648	648	11 member, the electric cooperative shall make minutes of any
649	649	12 meeting held after the effective date of this Act
650	650	13 available. Minutes shall include the votes of each member
651	651	14 of the board on all items for which approval was not
652	652	15 unanimous.
653	653	16 (3) At every regular meeting of the governing body of
654	654	17 an electric cooperative, members of the cooperative shall
655	655	18 be given an opportunity to address the board on any matter
656	656	19 concerning the policies and businesses of the cooperative.
657	657	20 The board may place reasonable, viewpoint-neutral
658	658	21 restrictions on the amount and duration of member comment.
659	659	22 (d) Each electric cooperative shall post on its website
660	660	23 its current rates. The electric cooperative shall keep and
661	661	24 make available to any member, upon request, all financial
662	662	25 audits of the electric cooperative conducted in the last 3
663	663	26 fiscal years.
664	664
665	665
666	666
667	667
668	668
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670	670
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673	673	HB5021 - 19 - LRB103 36729 LNS 66839 b
674	674	1 (e) Each electric cooperative shall adopt and post a
675	675	2 written policy governing the election of directors on its
676	676	3 website. The electric cooperative shall provide notice of the
677	677	4 policy at the time a person becomes a member, as a bill insert
678	678	5 at least once per year, and on request. The policy shall
679	679	6 contain true and complete information on the following:
680	680	7 (1) Who is entitled to vote in an election, including
681	681	8 how member-cooperatives may vote.
682	682	9 (2) How a member may obtain and cast a ballot.
683	683	10 (3) How a member may become a candidate for the board
684	684	11 or any other elected leadership positions.
685	685	12 (f) At least 60 days before each board election, the
686	686	13 electric cooperative shall post a list of candidates and
687	687	14 deadline to return ballots on its website and leave the
688	688	15 information posted until the election has concluded. The same
689	689	16 information shall be included as part of a bill insert for a
690	690	17 billing cycle occurring at no more than 60 but no fewer than 15
691	691	18 days prior to the deadline to return ballots.
692	692	19 (g) Each candidate for a position on the board of
693	693	20 directors who has qualified under the electric cooperative's
694	694	21 bylaws is entitled to receive a membership list in electronic
695	695	22 format upon receipt and verification of any candidacy
696	696	23 requirements. The membership list must include the names and
697	697	24 addresses of all members as they appear in the electric
698	698	25 cooperative's records.
699	699
700	700
701	701
702	702
703	703
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705	705
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709	709	1 Section 40. Conflict of interest disclosures.
710	710	2 (a) Each electric cooperative, municipality, and municipal
711	711	3 power agency shall adopt, and post publicly on its website,
712	712	4 written policies concerning:
713	713	5 (1) The compensation provided to a director on the
714	714	6 board of directors, including information on any
715	715	7 authorized per diem amounts, and the values of other
716	716	8 benefits, services, or goods that a director receives.
717	717	9 (2) The disclosure of any gifts received by a director
718	718	10 in excess of a de minimis amount.
719	719	11 (3) The requirements and procedures for a director on
720	720	12 the board of directors to disclose in writing any
721	721	13 conflicts of interest. At a minimum, the policy must
722	722	14 require disclosure when a decision before the board could
723	723	15 provide directly and as a proximate result of the decision
724	724	16 a financial or other material benefit to:
725	725	17 (A) The director, if the benefit is unique to that
726	726	18 director and not shared by similarly situated
727	727	19 cooperative members.
728	728	20 (B) A parent, grandparent, spouse, partner in a
729	729	21 civil union, child, or sibling of the director, if the
730	730	22 benefit is unique to that director and not shared by
731	731	23 similarly situated cooperative members.
732	732	24 (C) An entity in which the director is an officer
733	733	25 or director or has a financial interest not shared by
734	734	26 similarly situated cooperative members.
735	735
736	736
737	737
738	738
739	739
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741	741
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745	745	1 (b) Each electric cooperative shall disclose on its
746	746	2 website all lobbying activities as defined by Section 2 of the
747	747	3 Lobbyist Registration Act and the amount of expenditures on
748	748	4 such activities on an annual basis. Where the electric
749	749	5 cooperative is a member of a trade association or other
750	750	6 organization that engages in lobbying activities, the electric
751	751	7 cooperative shall post the amount of dues or other
752	752	8 expenditures paid by the cooperative to such an organization
753	753	9 and what percentage of the organization or association's
754	754	10 budget is spent on lobbying activities.
755	755	11 Section 45. The Open Meetings Act is amended by changing
756	756	12 Section 2 as follows:
757	757	13 (5 ILCS 120/2) (from Ch. 102, par. 42)
758	758	14 Sec. 2. Open meetings.
759	759	15 (a) Openness required. All meetings of public bodies shall
760	760	16 be open to the public unless excepted in subsection (c) and
761	761	17 closed in accordance with Section 2a.
762	762	18 (b) Construction of exceptions. The exceptions contained
763	763	19 in subsection (c) are in derogation of the requirement that
764	764	20 public bodies meet in the open, and therefore, the exceptions
765	765	21 are to be strictly construed, extending only to subjects
766	766	22 clearly within their scope. The exceptions authorize but do
767	767	23 not require the holding of a closed meeting to discuss a
768	768	24 subject included within an enumerated exception.
769	769
770	770
771	771
772	772
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775	775
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779	779	1 (c) Exceptions. A public body may hold closed meetings to
780	780	2 consider the following subjects:
781	781	3 (1) The appointment, employment, compensation,
782	782	4 discipline, performance, or dismissal of specific
783	783	5 employees, specific individuals who serve as independent
784	784	6 contractors in a park, recreational, or educational
785	785	7 setting, or specific volunteers of the public body or
786	786	8 legal counsel for the public body, including hearing
787	787	9 testimony on a complaint lodged against an employee, a
788	788	10 specific individual who serves as an independent
789	789	11 contractor in a park, recreational, or educational
790	790	12 setting, or a volunteer of the public body or against
791	791	13 legal counsel for the public body to determine its
792	792	14 validity. However, a meeting to consider an increase in
793	793	15 compensation to a specific employee of a public body that
794	794	16 is subject to the Local Government Wage Increase
795	795	17 Transparency Act may not be closed and shall be open to the
796	796	18 public and posted and held in accordance with this Act.
797	797	19 (2) Collective negotiating matters between the public
798	798	20 body and its employees or their representatives, or
799	799	21 deliberations concerning salary schedules for one or more
800	800	22 classes of employees.
801	801	23 (3) The selection of a person to fill a public office,
802	802	24 as defined in this Act, including a vacancy in a public
803	803	25 office, when the public body is given power to appoint
804	804	26 under law or ordinance, or the discipline, performance or
805	805
806	806
807	807
808	808
809	809
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811	811
812	812
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815	815	1 removal of the occupant of a public office, when the
816	816	2 public body is given power to remove the occupant under
817	817	3 law or ordinance.
818	818	4 (4) Evidence or testimony presented in open hearing,
819	819	5 or in closed hearing where specifically authorized by law,
820	820	6 to a quasi-adjudicative body, as defined in this Act,
821	821	7 provided that the body prepares and makes available for
822	822	8 public inspection a written decision setting forth its
823	823	9 determinative reasoning.
824	824	10 (4.5) Evidence or testimony presented to a school
825	825	11 board regarding denial of admission to school events or
826	826	12 property pursuant to Section 24-24 of the School Code,
827	827	13 provided that the school board prepares and makes
828	828	14 available for public inspection a written decision setting
829	829	15 forth its determinative reasoning.
830	830	16 (5) The purchase or lease of real property for the use
831	831	17 of the public body, including meetings held for the
832	832	18 purpose of discussing whether a particular parcel should
833	833	19 be acquired.
834	834	20 (6) The setting of a price for sale or lease of
835	835	21 property owned by the public body.
836	836	22 (7) The sale or purchase of securities, investments,
837	837	23 or investment contracts. This exception shall not apply to
838	838	24 the investment of assets or income of funds deposited into
839	839	25 the Illinois Prepaid Tuition Trust Fund.
840	840	26 (8) Security procedures, school building safety and
841	841
842	842
843	843
844	844
845	845
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847	847
848	848
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850	850	HB5021 - 24 - LRB103 36729 LNS 66839 b
851	851	1 security, and the use of personnel and equipment to
852	852	2 respond to an actual, a threatened, or a reasonably
853	853	3 potential danger to the safety of employees, students,
854	854	4 staff, the public, or public property.
855	855	5 (9) Student disciplinary cases.
856	856	6 (10) The placement of individual students in special
857	857	7 education programs and other matters relating to
858	858	8 individual students.
859	859	9 (11) Litigation, when an action against, affecting or
860	860	10 on behalf of the particular public body has been filed and
861	861	11 is pending before a court or administrative tribunal, or
862	862	12 when the public body finds that an action is probable or
863	863	13 imminent, in which case the basis for the finding shall be
864	864	14 recorded and entered into the minutes of the closed
865	865	15 meeting.
866	866	16 (12) The establishment of reserves or settlement of
867	867	17 claims as provided in the Local Governmental and
868	868	18 Governmental Employees Tort Immunity Act, if otherwise the
869	869	19 disposition of a claim or potential claim might be
870	870	20 prejudiced, or the review or discussion of claims, loss or
871	871	21 risk management information, records, data, advice or
872	872	22 communications from or with respect to any insurer of the
873	873	23 public body or any intergovernmental risk management
874	874	24 association or self insurance pool of which the public
875	875	25 body is a member.
876	876	26 (13) Conciliation of complaints of discrimination in
877	877
878	878
879	879
880	880
881	881
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883	883
884	884
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887	887	1 the sale or rental of housing, when closed meetings are
888	888	2 authorized by the law or ordinance prescribing fair
889	889	3 housing practices and creating a commission or
890	890	4 administrative agency for their enforcement.
891	891	5 (14) Informant sources, the hiring or assignment of
892	892	6 undercover personnel or equipment, or ongoing, prior or
893	893	7 future criminal investigations, when discussed by a public
894	894	8 body with criminal investigatory responsibilities.
895	895	9 (15) Professional ethics or performance when
896	896	10 considered by an advisory body appointed to advise a
897	897	11 licensing or regulatory agency on matters germane to the
898	898	12 advisory body's field of competence.
899	899	13 (16) Self evaluation, practices and procedures or
900	900	14 professional ethics, when meeting with a representative of
901	901	15 a statewide association of which the public body is a
902	902	16 member.
903	903	17 (17) The recruitment, credentialing, discipline or
904	904	18 formal peer review of physicians or other health care
905	905	19 professionals, or for the discussion of matters protected
906	906	20 under the federal Patient Safety and Quality Improvement
907	907	21 Act of 2005, and the regulations promulgated thereunder,
908	908	22 including 42 C.F.R. Part 3 (73 FR 70732), or the federal
909	909	23 Health Insurance Portability and Accountability Act of
910	910	24 1996, and the regulations promulgated thereunder,
911	911	25 including 45 C.F.R. Parts 160, 162, and 164, by a
912	912	26 hospital, or other institution providing medical care,
913	913
914	914
915	915
916	916
917	917
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919	919
920	920
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923	923	1 that is operated by the public body.
924	924	2 (18) Deliberations for decisions of the Prisoner
925	925	3 Review Board.
926	926	4 (19) Review or discussion of applications received
927	927	5 under the Experimental Organ Transplantation Procedures
928	928	6 Act.
929	929	7 (20) The classification and discussion of matters
930	930	8 classified as confidential or continued confidential by
931	931	9 the State Government Suggestion Award Board.
932	932	10 (21) Discussion of minutes of meetings lawfully closed
933	933	11 under this Act, whether for purposes of approval by the
934	934	12 body of the minutes or semi-annual review of the minutes
935	935	13 as mandated by Section 2.06.
936	936	14 (22) Deliberations for decisions of the State
937	937	15 Emergency Medical Services Disciplinary Review Board.
938	938	16 (23) The operation by a municipality of a municipal
939	939	17 utility or the operation of a municipal power agency or
940	940	18 municipal natural gas agency when the discussion involves
941	941	19 (i) trade secrets, (ii) ongoing contract negotiations or
942	942	20 results of a request for proposals relating to the
943	943	21 purchase, sale, or delivery of electricity or natural gas
944	944	22 from nonaffiliate entities, or (iii) information
945	945	23 prohibited from disclosure by a regional transmission
946	946	24 organization to ensure the integrity of competitive
947	947	25 markets contracts relating to the purchase, sale, or
948	948	26 delivery of electricity or natural gas or (ii) the results
949	949
950	950
951	951
952	952
953	953
954	954	HB5021 - 26 - LRB103 36729 LNS 66839 b
955	955
956	956
957	957	HB5021- 27 -LRB103 36729 LNS 66839 b HB5021 - 27 - LRB103 36729 LNS 66839 b
958	958	HB5021 - 27 - LRB103 36729 LNS 66839 b
959	959	1 or conclusions of load forecast studies.
960	960	2 (24) Meetings of a residential health care facility
961	961	3 resident sexual assault and death review team or the
962	962	4 Executive Council under the Abuse Prevention Review Team
963	963	5 Act.
964	964	6 (25) Meetings of an independent team of experts under
965	965	7 Brian's Law.
966	966	8 (26) Meetings of a mortality review team appointed
967	967	9 under the Department of Juvenile Justice Mortality Review
968	968	10 Team Act.
969	969	11 (27) (Blank).
970	970	12 (28) Correspondence and records (i) that may not be
971	971	13 disclosed under Section 11-9 of the Illinois Public Aid
972	972	14 Code or (ii) that pertain to appeals under Section 11-8 of
973	973	15 the Illinois Public Aid Code.
974	974	16 (29) Meetings between internal or external auditors
975	975	17 and governmental audit committees, finance committees, and
976	976	18 their equivalents, when the discussion involves internal
977	977	19 control weaknesses, identification of potential fraud risk
978	978	20 areas, known or suspected frauds, and fraud interviews
979	979	21 conducted in accordance with generally accepted auditing
980	980	22 standards of the United States of America.
981	981	23 (30) Those meetings or portions of meetings of a
982	982	24 fatality review team or the Illinois Fatality Review Team
983	983	25 Advisory Council during which a review of the death of an
984	984	26 eligible adult in which abuse or neglect is suspected,
985	985
986	986
987	987
988	988
989	989
990	990	HB5021 - 27 - LRB103 36729 LNS 66839 b
991	991
992	992
993	993	HB5021- 28 -LRB103 36729 LNS 66839 b HB5021 - 28 - LRB103 36729 LNS 66839 b
994	994	HB5021 - 28 - LRB103 36729 LNS 66839 b
995	995	1 alleged, or substantiated is conducted pursuant to Section
996	996	2 15 of the Adult Protective Services Act.
997	997	3 (31) Meetings and deliberations for decisions of the
998	998	4 Concealed Carry Licensing Review Board under the Firearm
999	999	5 Concealed Carry Act.
1000	1000	6 (32) Meetings between the Regional Transportation
1001	1001	7 Authority Board and its Service Boards when the discussion
1002	1002	8 involves review by the Regional Transportation Authority
1003	1003	9 Board of employment contracts under Section 28d of the
1004	1004	10 Metropolitan Transit Authority Act and Sections 3A.18 and
1005	1005	11 3B.26 of the Regional Transportation Authority Act.
1006	1006	12 (33) Those meetings or portions of meetings of the
1007	1007	13 advisory committee and peer review subcommittee created
1008	1008	14 under Section 320 of the Illinois Controlled Substances
1009	1009	15 Act during which specific controlled substance prescriber,
1010	1010	16 dispenser, or patient information is discussed.
1011	1011	17 (34) Meetings of the Tax Increment Financing Reform
1012	1012	18 Task Force under Section 2505-800 of the Department of
1013	1013	19 Revenue Law of the Civil Administrative Code of Illinois.
1014	1014	20 (35) Meetings of the group established to discuss
1015	1015	21 Medicaid capitation rates under Section 5-30.8 of the
1016	1016	22 Illinois Public Aid Code.
1017	1017	23 (36) Those deliberations or portions of deliberations
1018	1018	24 for decisions of the Illinois Gaming Board in which there
1019	1019	25 is discussed any of the following: (i) personal,
1020	1020	26 commercial, financial, or other information obtained from
1021	1021
1022	1022
1023	1023
1024	1024
1025	1025
1026	1026	HB5021 - 28 - LRB103 36729 LNS 66839 b
1027	1027
1028	1028
1029	1029	HB5021- 29 -LRB103 36729 LNS 66839 b HB5021 - 29 - LRB103 36729 LNS 66839 b
1030	1030	HB5021 - 29 - LRB103 36729 LNS 66839 b
1031	1031	1 any source that is privileged, proprietary, confidential,
1032	1032	2 or a trade secret; or (ii) information specifically
1033	1033	3 exempted from the disclosure by federal or State law.
1034	1034	4 (37) Deliberations for decisions of the Illinois Law
1035	1035	5 Enforcement Training Standards Board, the Certification
1036	1036	6 Review Panel, and the Illinois State Police Merit Board
1037	1037	7 regarding certification and decertification.
1038	1038	8 (38) Meetings of the Ad Hoc Statewide Domestic
1039	1039	9 Violence Fatality Review Committee of the Illinois
1040	1040	10 Criminal Justice Information Authority Board that occur in
1041	1041	11 closed executive session under subsection (d) of Section
1042	1042	12 35 of the Domestic Violence Fatality Review Act.
1043	1043	13 (39) Meetings of the regional review teams under
1044	1044	14 subsection (a) of Section 75 of the Domestic Violence
1045	1045	15 Fatality Review Act.
1046	1046	16 (40) Meetings of the Firearm Owner's Identification
1047	1047	17 Card Review Board under Section 10 of the Firearm Owners
1048	1048	18 Identification Card Act.
1049	1049	19 (d) Definitions. For purposes of this Section:
1050	1050	20 "Employee" means a person employed by a public body whose
1051	1051	21 relationship with the public body constitutes an
1052	1052	22 employer-employee relationship under the usual common law
1053	1053	23 rules, and who is not an independent contractor.
1054	1054	24 "Public office" means a position created by or under the
1055	1055	25 Constitution or laws of this State, the occupant of which is
1056	1056	26 charged with the exercise of some portion of the sovereign
1057	1057
1058	1058
1059	1059
1060	1060
1061	1061
1062	1062	HB5021 - 29 - LRB103 36729 LNS 66839 b
1063	1063
1064	1064
1065	1065	HB5021- 30 -LRB103 36729 LNS 66839 b HB5021 - 30 - LRB103 36729 LNS 66839 b
1066	1066	HB5021 - 30 - LRB103 36729 LNS 66839 b
1067	1067	1 power of this State. The term "public office" shall include
1068	1068	2 members of the public body, but it shall not include
1069	1069	3 organizational positions filled by members thereof, whether
1070	1070	4 established by law or by a public body itself, that exist to
1071	1071	5 assist the body in the conduct of its business.
1072	1072	6 "Quasi-adjudicative body" means an administrative body
1073	1073	7 charged by law or ordinance with the responsibility to conduct
1074	1074	8 hearings, receive evidence or testimony and make
1075	1075	9 determinations based thereon, but does not include local
1076	1076	10 electoral boards when such bodies are considering petition
1077	1077	11 challenges.
1078	1078	12 (e) Final action. No final action may be taken at a closed
1079	1079	13 meeting. Final action shall be preceded by a public recital of
1080	1080	14 the nature of the matter being considered and other
1081	1081	15 information that will inform the public of the business being
1082	1082	16 conducted.
1083	1083	17 (Source: P.A. 102-237, eff. 1-1-22; 102-520, eff. 8-20-21;
1084	1084	18 102-558, eff. 8-20-21; 102-813, eff. 5-13-22; 103-311, eff.
1085	1085	19 7-28-23.)
1086	1086	20 Section 50. The Illinois Municipal Code is amended by
1087	1087	21 changing Sections 11-119.1-4 and 11-119.1-10 and by adding
1088	1088	22 Section 11-119.1-5.5 as follows:
1089	1089	23 (65 ILCS 5/11-119.1-4) (from Ch. 24, par. 11-119.1-4)
1090	1090	24 Sec. 11-119.1-4. Municipal Power Agencies.
1091	1091
1092	1092
1093	1093
1094	1094
1095	1095
1096	1096	HB5021 - 30 - LRB103 36729 LNS 66839 b
1097	1097
1098	1098
1099	1099	HB5021- 31 -LRB103 36729 LNS 66839 b HB5021 - 31 - LRB103 36729 LNS 66839 b
1100	1100	HB5021 - 31 - LRB103 36729 LNS 66839 b
1101	1101	1 A. Any 2 or more municipalities, contiguous or
1102	1102	2 noncontiguous, and which operate an electric utility system,
1103	1103	3 may form a municipal power agency by the execution of an agency
1104	1104	4 agreement authorized by an ordinance adopted by the governing
1105	1105	5 body of each municipality. The agency agreement may state:
1106	1106	6 (1) that the municipal power agency is created and
1107	1107	7 incorporated under the provisions of this Division as a
1108	1108	8 body politic and corporate, municipal corporation and unit
1109	1109	9 of local government of the State of Illinois;
1110	1110	10 (2) the name of the agency and the date of its
1111	1111	11 establishment;
1112	1112	12 (3) that names of the municipalities which have
1113	1113	13 adopted the agency agreement and constitute the initial
1114	1114	14 members of the municipal power agency;
1115	1115	15 (4) the names and addresses of the persons initially
1116	1116	16 appointed in the ordinances adopting the agency agreement
1117	1117	17 to serve on the Board of Directors and act as the
1118	1118	18 representatives of the municipalities, respectively, in
1119	1119	19 the exercise of their powers as members;
1120	1120	20 (5) the limitations, if any, upon the terms of office
1121	1121	21 of the directors, provided that such directors shall
1122	1122	22 always be selected and vacancies in their offices declared
1123	1123	23 and filled by ordinances adopted by the governing body of
1124	1124	24 the respective municipalities;
1125	1125	25 (6) the location by city, village or incorporated town
1126	1126	26 in the State of Illinois of the principal office of the
1127	1127
1128	1128
1129	1129
1130	1130
1131	1131
1132	1132	HB5021 - 31 - LRB103 36729 LNS 66839 b
1133	1133
1134	1134
1135	1135	HB5021- 32 -LRB103 36729 LNS 66839 b HB5021 - 32 - LRB103 36729 LNS 66839 b
1136	1136	HB5021 - 32 - LRB103 36729 LNS 66839 b
1137	1137	1 municipal power agency;
1138	1138	2 (7) provisions for the disposition, division or
1139	1139	3 distribution of obligations, property and assets of the
1140	1140	4 municipal power agency upon dissolution; and
1141	1141	5 (8) any other provisions for regulating the business
1142	1142	6 of the municipal power agency or the conduct of its
1143	1143	7 affairs which may be agreed to by the member
1144	1144	8 municipalities, consistent with this Division, including,
1145	1145	9 without limitation, any provisions for weighted voting
1146	1146	10 among the member municipalities or by the directors.
1147	1147	11 B. The presiding officer of the Board of Directors of any
1148	1148	12 municipal power agency established pursuant to this Division
1149	1149	13 or such other officer selected by the Board of Directors,
1150	1150	14 within 3 months after establishment, shall file a certified
1151	1151	15 copy of the agency agreement and a list of the municipalities
1152	1152	16 which have adopted the agreement with the recorder of deeds of
1153	1153	17 the county in which the principal office is located. The
1154	1154	18 recorder of deeds shall record this certified copy and list
1155	1155	19 and shall immediately transmit the certified copy and list to
1156	1156	20 the Secretary of State, together with his certificate of
1157	1157	21 recordation. The Secretary of State shall file these documents
1158	1158	22 and issue his certificate of approval over his signature and
1159	1159	23 the Great Seal of the State. The Secretary of State shall make
1160	1160	24 and keep a register of municipal power agencies established
1161	1161	25 under this Division.
1162	1162	26 C. Each municipality which becomes a member of the
1163	1163
1164	1164
1165	1165
1166	1166
1167	1167
1168	1168	HB5021 - 32 - LRB103 36729 LNS 66839 b
1169	1169
1170	1170
1171	1171	HB5021- 33 -LRB103 36729 LNS 66839 b HB5021 - 33 - LRB103 36729 LNS 66839 b
1172	1172	HB5021 - 33 - LRB103 36729 LNS 66839 b
1173	1173	1 municipal power agency shall appoint a representative to serve
1174	1174	2 on the Board of Directors, which representative may be a
1175	1175	3 member of the governing body of the municipality. Each
1176	1176	4 appointment shall be made by the mayor, or president, subject
1177	1177	5 to the confirmation of the governing body. The directors so
1178	1178	6 appointed shall hold office for a term of 3 years, or until a
1179	1179	7 successor has been duly appointed and qualified, except that
1180	1180	8 the directors first appointed shall determine by lot at their
1181	1181	9 initial meeting the respective directors which shall serve for
1182	1182	10 a term of one, 2 or 3 years from the date of that meeting. A
1183	1183	11 vacancy shall be filled for the balance of the unexpired term
1184	1184	12 in the same manner as the original appointment.
1185	1185	13 The Board of Directors is the corporate authority of the
1186	1186	14 municipal power agency and shall exercise all the powers and
1187	1187	15 manage and control all of the affairs and property of the
1188	1188	16 agency. The Board of Directors shall have full power to pass
1189	1189	17 all necessary ordinances, resolutions, rules and regulations
1190	1190	18 for the proper management and conduct of the business of the
1191	1191	19 board, and for carrying into effect the objects for which the
1192	1192	20 agency was established.
1193	1193	21 At the initial meeting of the Board of Directors to be held
1194	1194	22 within 30 days after the date of establishment of the
1195	1195	23 municipal power agency, the directors shall elect from their
1196	1196	24 members a presiding officer to preside over the meetings of
1197	1197	25 the Board of Directors and an alternative presiding officer
1198	1198	26 and may elect an executive board. The Board of Directors shall
1199	1199
1200	1200
1201	1201
1202	1202
1203	1203
1204	1204	HB5021 - 33 - LRB103 36729 LNS 66839 b
1205	1205
1206	1206
1207	1207	HB5021- 34 -LRB103 36729 LNS 66839 b HB5021 - 34 - LRB103 36729 LNS 66839 b
1208	1208	HB5021 - 34 - LRB103 36729 LNS 66839 b
1209	1209	1 determine and designate in the agency's bylaws the titles for
1210	1210	2 the presiding officers. The directors shall also elect a
1211	1211	3 secretary and treasurer, who need not be directors. The board
1212	1212	4 may select such other officers, employees and agents as deemed
1213	1213	5 to be necessary, who need not be directors or residents of any
1214	1214	6 of the municipalities which are members of the municipal power
1215	1215	7 agency. The board may designate appropriate titles for all
1216	1216	8 other officers, employees, and agents. All persons selected by
1217	1217	9 the board shall hold their respective offices during the
1218	1218	10 pleasure of the board, and give such bond as may be required by
1219	1219	11 the board.
1220	1220	12 D. The bylaws of the municipal power agency, and any
1221	1221	13 amendments thereto, shall be adopted by the Board of Directors
1222	1222	14 by a majority vote (adjusted for weighted voting, if provided
1223	1223	15 in the Agency Agreement) to provide the following:
1224	1224	16 (1) the conditions and obligations of membership, if
1225	1225	17 any;
1226	1226	18 (2) the manner and time of calling regular and special
1227	1227	19 meetings of the Board of Directors;
1228	1228	20 (3) the procedural rules of the Board of Directors;
1229	1229	21 (4) the composition, powers and responsibilities of
1230	1230	22 any committee or executive board;
1231	1231	23 (5) the rights and obligations of new members,
1232	1232	24 conditions for the termination of membership, including a
1233	1233	25 formula for the determination of required termination
1234	1234	26 payments, if any, and the disposition of rights and
1235	1235
1236	1236
1237	1237
1238	1238
1239	1239
1240	1240	HB5021 - 34 - LRB103 36729 LNS 66839 b
1241	1241
1242	1242
1243	1243	HB5021- 35 -LRB103 36729 LNS 66839 b HB5021 - 35 - LRB103 36729 LNS 66839 b
1244	1244	HB5021 - 35 - LRB103 36729 LNS 66839 b
1245	1245	1 obligations upon termination of membership; and
1246	1246	2 (6) such other rules or provisions for regulating the
1247	1247	3 affairs of the municipal power agency as the board shall
1248	1248	4 determine to be necessary.
1249	1249	5 E. Every municipal power agency shall maintain an office
1250	1250	6 in the State of Illinois to be known as its principal office.
1251	1251	7 When a municipal power agency desires to change the location
1252	1252	8 of such office, it shall file with the Secretary of State a
1253	1253	9 certificate of change of location, stating the new address and
1254	1254	10 the effective date of change. Meetings of the Board of
1255	1255	11 Directors may be held at any place within the State of
1256	1256	12 Illinois, designated by the Board of Directors, after notice.
1257	1257	13 Unless otherwise provided by the bylaws, an act of the
1258	1258	14 majority of the directors present at a meeting at which a
1259	1259	15 quorum is present is the act of the Board of Directors.
1260	1260	16 F. The Board of Directors shall hold at least one meeting
1261	1261	17 each year for the election of officers and for the transaction
1262	1262	18 of any other business. Special meetings of the Board of
1263	1263	19 Directors may be called for any purpose upon written request
1264	1264	20 to the presiding officer of the Board of Directors or
1265	1265	21 secretary to call the meeting. Such officer shall give notice
1266	1266	22 of the meeting to be held not less than 10 days and not more
1267	1267	23 than 60 days after receipt of such request. Unless the bylaws
1268	1268	24 provide for a different percentage, a quorum for a meeting of
1269	1269	25 the Board of Directors is a majority of all members then in
1270	1270	26 office. All meetings of the board shall be held in compliance
1271	1271
1272	1272
1273	1273
1274	1274
1275	1275
1276	1276	HB5021 - 35 - LRB103 36729 LNS 66839 b
1277	1277
1278	1278
1279	1279	HB5021- 36 -LRB103 36729 LNS 66839 b HB5021 - 36 - LRB103 36729 LNS 66839 b
1280	1280	HB5021 - 36 - LRB103 36729 LNS 66839 b
1281	1281	1 with the provisions of "An Act in relation to meetings",
1282	1282	2 approved July 11, 1957, as amended.
1283	1283	3 G. The agency agreement may be amended as proposed at any
1284	1284	4 meeting of the Board of Directors for which notice, stating
1285	1285	5 the purpose, shall be given to each director and, unless the
1286	1286	6 bylaws prescribe otherwise, such amendment shall become
1287	1287	7 effective when ratified by ordinances adopted by a majority of
1288	1288	8 the governing bodies of the member municipalities. Each
1289	1289	9 amendment, duly certified, shall be recorded and filed in the
1290	1290	10 same manner as for the original agreement.
1291	1291	11 H. Each member municipality shall have full power and
1292	1292	12 authority, subject to the provisions of its charter and laws
1293	1293	13 regarding local finance, to appropriate money for the payment
1294	1294	14 of the expenses of the municipal power agency and of its
1295	1295	15 representative in exercising its functions as a member of the
1296	1296	16 municipal power agency.
1297	1297	17 I. Any additional municipality which operates an electric
1298	1298	18 utility system may join the municipal power agency, or any
1299	1299	19 member municipality may withdraw therefrom consistent with the
1300	1300	20 bylaws of the municipal power agency, and upon payment of any
1301	1301	21 termination obligations as described in subsection D upon the
1302	1302	22 approval by ordinance adopted by the governing body of the
1303	1303	23 majority of the municipalities which are then members of the
1304	1304	24 municipal power agency. Any new member shall agree to assume
1305	1305	25 its proportionate share of the outstanding obligations of the
1306	1306	26 municipal power agency and any member permitted to withdraw
1307	1307
1308	1308
1309	1309
1310	1310
1311	1311
1312	1312	HB5021 - 36 - LRB103 36729 LNS 66839 b
1313	1313
1314	1314
1315	1315	HB5021- 37 -LRB103 36729 LNS 66839 b HB5021 - 37 - LRB103 36729 LNS 66839 b
1316	1316	HB5021 - 37 - LRB103 36729 LNS 66839 b
1317	1317	1 shall remain obligated to make payments under any outstanding
1318	1318	2 contract or agreement with the municipal power agency or to
1319	1319	3 comply with any exit or early termination provisions set forth
1320	1320	4 in that contract or agreement. Any such change in membership
1321	1321	5 shall be recorded and filed in the same manner as for the
1322	1322	6 original agreement.
1323	1323	7 J. Any 2 or more municipal power agencies organized
1324	1324	8 pursuant to this Division may consolidate to form a new
1325	1325	9 municipal power agency when approved by ordinance adopted by
1326	1326	10 the governing body of each municipality which is a member of
1327	1327	11 the respective municipal power agency and by the execution of
1328	1328	12 an agency agreement as provided in this Section.
1329	1329	13 (Source: P.A. 96-204, eff. 1-1-10.)
1330	1330	14 (65 ILCS 5/11-119.1-5.5 new)
1331	1331	15 Sec. 11-119.1-5.5. Agency records, budgets, and quarterly
1332	1332	16 reports.
1333	1333	17 (a) A municipal power agency shall keep accurate accounts
1334	1334	18 and records of its assets, liabilities, revenues, and
1335	1335	19 expenditures in accordance with generally accepted accounting
1336	1336	20 principles. Such accounts and records shall include, but are
1337	1337	21 not limited to, depreciation, operating and maintenance
1338	1338	22 expenses for all generation and transmission assets, fuel
1339	1339	23 costs, cost and revenue from the purchase or sale of
1340	1340	24 environmental compliance credits, revenue from energy,
1341	1341	25 capacity, and ancillary market sales, all payments received
1342	1342
1343	1343
1344	1344
1345	1345
1346	1346
1347	1347	HB5021 - 37 - LRB103 36729 LNS 66839 b
1348	1348
1349	1349
1350	1350	HB5021- 38 -LRB103 36729 LNS 66839 b HB5021 - 38 - LRB103 36729 LNS 66839 b
1351	1351	HB5021 - 38 - LRB103 36729 LNS 66839 b
1352	1352	1 from member municipalities, membership dues or other payments
1353	1353	2 made to trade associations or industry organizations, and
1354	1354	3 lobbying expenditures. Such records shall be audited on an
1355	1355	4 annual basis by an independent auditor using generally
1356	1356	5 accepted auditing standards and shall include contents as set
1357	1357	6 forth in Section 8-8-5, and shall be filed with the
1358	1358	7 Comptroller as described by Section 8-8-7.
1359	1359	8 (b) A municipal power agency shall, on an annual basis,
1360	1360	9 prepare one-year and 5-year budgets that include all revenues
1361	1361	10 and expenses, including, but not limited to, those categories
1362	1362	11 described in subsection (a). As part of each one-year budget,
1363	1363	12 the municipal power agency shall include a report identifying
1364	1364	13 and explaining any variance from the previous annual budget of
1365	1365	14 5% or greater in any expenditure or revenue line item. Such
1366	1366	15 budgets shall be provided to member municipalities no less
1367	1367	16 than 60 days prior to any meeting of the municipal power agency
1368	1368	17 during which action on the budget is or will be part of the
1369	1369	18 agency agenda.
1370	1370	19 (c) The municipal power agency shall post, on a publicly
1371	1371	20 available website, all one-year and 5-year budgets required
1372	1372	21 under subsection (b) and the annual audited financial
1373	1373	22 statements required under subsection (a).
1374	1374	23 (d) The municipal power agency shall make available, upon
1375	1375	24 request to any of its member municipalities, access to all
1376	1376	25 municipal power agency all records and accounts and all
1377	1377	26 financial information relating to ownership and operation of
1378	1378
1379	1379
1380	1380
1381	1381
1382	1382
1383	1383	HB5021 - 38 - LRB103 36729 LNS 66839 b
1384	1384
1385	1385
1386	1386	HB5021- 39 -LRB103 36729 LNS 66839 b HB5021 - 39 - LRB103 36729 LNS 66839 b
1387	1387	HB5021 - 39 - LRB103 36729 LNS 66839 b
1388	1388	1 agency assets and the generation, procurement, and delivery of
1389	1389	2 electricity to which the agency has access, including, but not
1390	1390	3 limited to, unit scheduling information, market revenue and
1391	1391	4 off-system sales data, and fuel and other variable cost
1392	1392	5 information. Such information shall be provided in a timely
1393	1393	6 manner and through reasonable means, and members shall be
1394	1394	7 permitted to make copies of any documents retained solely by
1395	1395	8 the agency. Such access shall be provided without regard to
1396	1396	9 any nondisclosure agreement that has been or may be adopted by
1397	1397	10 the municipal power agency.
1398	1398	11 (e) The municipal power agency shall prepare, on a
1399	1399	12 quarterly basis, a report to its member municipalities
1400	1400	13 describing all expenditures made for the purpose of lobbying,
1401	1401	14 as both terms are defined by Section 2 of the Lobbyist
1402	1402	15 Registration Act, and a brief summary of the topics and
1403	1403	16 positions on which lobbying activities were undertaken. Where
1404	1404	17 the municipal power agency is a member of an organization or
1405	1405	18 trade association that expends some or all of membership dues
1406	1406	19 on lobbying activities, the municipal power agency shall
1407	1407	20 include in this report the amount of those membership dues,
1408	1408	21 what proportion of those dues were spent on lobbying
1409	1409	22 activities, and the topics and positions on which lobbying
1410	1410	23 activities were undertaken by the organization or trade
1411	1411	24 association of which the municipal power agency is a member.
1412	1412	25 (65 ILCS 5/11-119.1-10) (from Ch. 24, par. 11-119.1-10)
1413	1413
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1423	1423	1 Sec. 11-119.1-10. Exercise of powers. A municipal power
1424	1424	2 agency may exercise any and all of the powers enumerated in
1425	1425	3 this Division, except the power of eminent domain, without the
1426	1426	4 consent and approval of the Illinois Commerce Commission. The
1427	1427	5 exercise of the power of eminent domain by a municipal power
1428	1428	6 agency shall be subject to the consent and approval of the
1429	1429	7 Illinois Commerce Commission in the same manner and to the
1430	1430	8 same extent as public utilities under the Public Utilities
1431	1431	9 Act, including the issuance of a certificate of public
1432	1432	10 convenience and necessity as provided for in Section 8-406 of
1433	1433	11 that Act. During the consideration of any petition for
1434	1434	12 authority to exercise the power of eminent domain the Illinois
1435	1435	13 Commerce Commission shall evaluate and give due consideration
1436	1436	14 to whether the project for which eminent domain is sought is
1437	1437	15 part of the preferred portfolio as described in subsection (d)
1438	1438	16 of Section 15 of the Municipal and Cooperative Electric
1439	1439	17 Utility Planning and Transparency Act, or least cost plans for
1440	1440	18 procuring renewable resources as described in subsections (f)
1441	1441	19 and (g) of Section 20 of the Municipal and Cooperative
1442	1442	20 Electric Utility Planning and Transparency Act and to the
1443	1443	21 impact of the acquisition on farmlands in the State with the
1444	1444	22 goal of preserving the land to the fullest extent reasonably
1445	1445	23 possible.
1446	1446	24 (Source: P.A. 90-416, eff. 1-1-98.)
1447	1447	25 Section 55. The Public Utilities Act is amended by
1448	1448
1449	1449
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1457	1457	HB5021 - 41 - LRB103 36729 LNS 66839 b
1458	1458	1 changing Sections 16-107.5 and 17-500 as follows:
1459	1459	2 (220 ILCS 5/16-107.5)
1460	1460	3 Sec. 16-107.5. Net electricity metering.
1461	1461	4 (a) The General Assembly finds and declares that a program
1462	1462	5 to provide net electricity metering, as defined in this
1463	1463	6 Section, for eligible customers can encourage private
1464	1464	7 investment in renewable energy resources, stimulate economic
1465	1465	8 growth, enhance the continued diversification of Illinois'
1466	1466	9 energy resource mix, and protect the Illinois environment.
1467	1467	10 Further, to achieve the goals of this Act that robust options
1468	1468	11 for customer-site distributed generation continue to thrive in
1469	1469	12 Illinois, the General Assembly finds that a predictable
1470	1470	13 transition must be ensured for customers between full net
1471	1471	14 metering at the retail electricity rate to the distribution
1472	1472	15 generation rebate described in Section 16-107.6.
1473	1473	16 (b) As used in this Section, (i) "community renewable
1474	1474	17 generation project" shall have the meaning set forth in
1475	1475	18 Section 1-10 of the Illinois Power Agency Act; (ii) "eligible
1476	1476	19 customer" means a retail customer that owns, hosts, or
1477	1477	20 operates, including any third-party owned systems, a solar,
1478	1478	21 wind, or other eligible renewable electrical generating
1479	1479	22 facility that is located on the customer's premises or
1480	1480	23 customer's side of the billing meter and is intended primarily
1481	1481	24 to offset the customer's own current or future electrical
1482	1482	25 requirements; (iii) "electricity provider" means an electric
1483	1483
1484	1484
1485	1485
1486	1486
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1492	1492	HB5021 - 42 - LRB103 36729 LNS 66839 b
1493	1493	1 utility or alternative retail electric supplier; (iv)
1494	1494	2 "eligible renewable electrical generating facility" means a
1495	1495	3 generator, which may include the co-location of an energy
1496	1496	4 storage system, that is interconnected under rules adopted by
1497	1497	5 the Commission and is powered by solar electric energy, wind,
1498	1498	6 dedicated crops grown for electricity generation, agricultural
1499	1499	7 residues, untreated and unadulterated wood waste, livestock
1500	1500	8 manure, anaerobic digestion of livestock or food processing
1501	1501	9 waste, fuel cells or microturbines powered by renewable fuels,
1502	1502	10 or hydroelectric energy; (v) "net electricity metering" (or
1503	1503	11 "net metering") means the measurement, during the billing
1504	1504	12 period applicable to an eligible customer, of the net amount
1505	1505	13 of electricity supplied by an electricity provider to the
1506	1506	14 customer or provided to the electricity provider by the
1507	1507	15 customer or subscriber; (vi) "subscriber" shall have the
1508	1508	16 meaning as set forth in Section 1-10 of the Illinois Power
1509	1509	17 Agency Act; (vii) "subscription" shall have the meaning set
1510	1510	18 forth in Section 1-10 of the Illinois Power Agency Act; (viii)
1511	1511	19 "energy storage system" means commercially available
1512	1512	20 technology that is capable of absorbing energy and storing it
1513	1513	21 for a period of time for use at a later time, including, but
1514	1514	22 not limited to, electrochemical, thermal, and
1515	1515	23 electromechanical technologies, and may be interconnected
1516	1516	24 behind the customer's meter or interconnected behind its own
1517	1517	25 meter; and (ix) "future electrical requirements" means modeled
1518	1518	26 electrical requirements upon occupation of a new or vacant
1519	1519
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1529	1529	1 property, and other reasonable expectations of future
1530	1530	2 electrical use, as well as, for occupied properties, a
1531	1531	3 reasonable approximation of the annual load of 2 electric
1532	1532	4 vehicles and, for non-electric heating customers, a reasonable
1533	1533	5 approximation of the incremental electric load associated with
1534	1534	6 fuel switching. The approximations shall be applied to the
1535	1535	7 appropriate net metering tariff and do not need to be unique to
1536	1536	8 each individual eligible customer. The utility shall submit
1537	1537	9 these approximations to the Commission for review,
1538	1538	10 modification, and approval; and (x) "electricity provider" and
1539	1539	11 "electric utility" includes municipalities and municipal power
1540	1540	12 agencies as defined in Section 11-119.3-1 of the Illinois
1541	1541	13 Municipal Code and electric cooperatives as defined in Section
1542	1542	14 3-119 of this Act.
1543	1543	15 (c) A net metering facility shall be equipped with
1544	1544	16 metering equipment that can measure the flow of electricity in
1545	1545	17 both directions at the same rate.
1546	1546	18 (1) For eligible customers whose electric service has
1547	1547	19 not been declared competitive pursuant to Section 16-113
1548	1548	20 of this Act as of July 1, 2011 and whose electric delivery
1549	1549	21 service is provided and measured on a kilowatt-hour basis
1550	1550	22 and electric supply service is not provided based on
1551	1551	23 hourly pricing, this shall typically be accomplished
1552	1552	24 through use of a single, bi-directional meter. If the
1553	1553	25 eligible customer's existing electric revenue meter does
1554	1554	26 not meet this requirement, the electricity provider shall
1555	1555
1556	1556
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1558	1558
1559	1559
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1565	1565	1 arrange for the local electric utility or a meter service
1566	1566	2 provider to install and maintain a new revenue meter at
1567	1567	3 the electricity provider's expense, which may be the smart
1568	1568	4 meter described by subsection (b) of Section 16-108.5 of
1569	1569	5 this Act.
1570	1570	6 (2) For eligible customers whose electric service has
1571	1571	7 not been declared competitive pursuant to Section 16-113
1572	1572	8 of this Act as of July 1, 2011 and whose electric delivery
1573	1573	9 service is provided and measured on a kilowatt demand
1574	1574	10 basis and electric supply service is not provided based on
1575	1575	11 hourly pricing, this shall typically be accomplished
1576	1576	12 through use of a dual channel meter capable of measuring
1577	1577	13 the flow of electricity both into and out of the
1578	1578	14 customer's facility at the same rate and ratio. If such
1579	1579	15 customer's existing electric revenue meter does not meet
1580	1580	16 this requirement, then the electricity provider shall
1581	1581	17 arrange for the local electric utility or a meter service
1582	1582	18 provider to install and maintain a new revenue meter at
1583	1583	19 the electricity provider's expense, which may be the smart
1584	1584	20 meter described by subsection (b) of Section 16-108.5 of
1585	1585	21 this Act.
1586	1586	22 (3) For all other eligible customers, until such time
1587	1587	23 as the local electric utility installs a smart meter, as
1588	1588	24 described by subsection (b) of Section 16-108.5 of this
1589	1589	25 Act, the electricity provider may arrange for the local
1590	1590	26 electric utility or a meter service provider to install
1591	1591
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1596	1596	HB5021 - 44 - LRB103 36729 LNS 66839 b
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1601	1601	1 and maintain metering equipment capable of measuring the
1602	1602	2 flow of electricity both into and out of the customer's
1603	1603	3 facility at the same rate and ratio, typically through the
1604	1604	4 use of a dual channel meter. If the eligible customer's
1605	1605	5 existing electric revenue meter does not meet this
1606	1606	6 requirement, then the costs of installing such equipment
1607	1607	7 shall be paid for by the customer.
1608	1608	8 (d) An electricity provider shall measure and charge or
1609	1609	9 credit for the net electricity supplied to eligible customers
1610	1610	10 or provided by eligible customers whose electric service has
1611	1611	11 not been declared competitive pursuant to Section 16-113 of
1612	1612	12 this Act as of July 1, 2011 and whose electric delivery service
1613	1613	13 is provided and measured on a kilowatt-hour basis and electric
1614	1614	14 supply service is not provided based on hourly pricing in the
1615	1615	15 following manner:
1616	1616	16 (1) If the amount of electricity used by the customer
1617	1617	17 during the billing period exceeds the amount of
1618	1618	18 electricity produced by the customer, the electricity
1619	1619	19 provider shall charge the customer for the net electricity
1620	1620	20 supplied to and used by the customer as provided in
1621	1621	21 subsection (e-5) of this Section.
1622	1622	22 (2) If the amount of electricity produced by a
1623	1623	23 customer during the billing period exceeds the amount of
1624	1624	24 electricity used by the customer during that billing
1625	1625	25 period, the electricity provider supplying that customer
1626	1626	26 shall apply a 1:1 kilowatt-hour credit to a subsequent
1627	1627
1628	1628
1629	1629
1630	1630
1631	1631
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1633	1633
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1636	1636	HB5021 - 46 - LRB103 36729 LNS 66839 b
1637	1637	1 bill for service to the customer for the net electricity
1638	1638	2 supplied to the electricity provider. The electricity
1639	1639	3 provider shall continue to carry over any excess
1640	1640	4 kilowatt-hour credits earned and apply those credits to
1641	1641	5 subsequent billing periods to offset any
1642	1642	6 customer-generator consumption in those billing periods
1643	1643	7 until all credits are used or until the end of the
1644	1644	8 annualized period.
1645	1645	9 (3) At the end of the year or annualized over the
1646	1646	10 period that service is supplied by means of net metering,
1647	1647	11 or in the event that the retail customer terminates
1648	1648	12 service with the electricity provider prior to the end of
1649	1649	13 the year or the annualized period, any remaining credits
1650	1650	14 in the customer's account shall expire.
1651	1651	15 (d-5) An electricity provider shall measure and charge or
1652	1652	16 credit for the net electricity supplied to eligible customers
1653	1653	17 or provided by eligible customers whose electric service has
1654	1654	18 not been declared competitive pursuant to Section 16-113 of
1655	1655	19 this Act as of July 1, 2011 and whose electric delivery service
1656	1656	20 is provided and measured on a kilowatt-hour basis and electric
1657	1657	21 supply service is provided based on hourly pricing or
1658	1658	22 time-of-use rates in the following manner:
1659	1659	23 (1) If the amount of electricity used by the customer
1660	1660	24 during any hourly period or time-of-use period exceeds the
1661	1661	25 amount of electricity produced by the customer, the
1662	1662	26 electricity provider shall charge the customer for the net
1663	1663
1664	1664
1665	1665
1666	1666
1667	1667
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1669	1669
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1672	1672	HB5021 - 47 - LRB103 36729 LNS 66839 b
1673	1673	1 electricity supplied to and used by the customer according
1674	1674	2 to the terms of the contract or tariff to which the same
1675	1675	3 customer would be assigned to or be eligible for if the
1676	1676	4 customer was not a net metering customer.
1677	1677	5 (2) If the amount of electricity produced by a
1678	1678	6 customer during any hourly period or time-of-use period
1679	1679	7 exceeds the amount of electricity used by the customer
1680	1680	8 during that hourly period or time-of-use period, the
1681	1681	9 energy provider shall apply a credit for the net
1682	1682	10 kilowatt-hours produced in such period. The credit shall
1683	1683	11 consist of an energy credit and a delivery service credit.
1684	1684	12 The energy credit shall be valued at the same price per
1685	1685	13 kilowatt-hour as the electric service provider would
1686	1686	14 charge for kilowatt-hour energy sales during that same
1687	1687	15 hourly period or time-of-use period. The delivery credit
1688	1688	16 shall be equal to the net kilowatt-hours produced in such
1689	1689	17 hourly period or time-of-use period times a credit that
1690	1690	18 reflects all kilowatt-hour based charges in the customer's
1691	1691	19 electric service rate, excluding energy charges.
1692	1692	20 (e) An electricity provider shall measure and charge or
1693	1693	21 credit for the net electricity supplied to eligible customers
1694	1694	22 whose electric service has not been declared competitive
1695	1695	23 pursuant to Section 16-113 of this Act as of July 1, 2011 and
1696	1696	24 whose electric delivery service is provided and measured on a
1697	1697	25 kilowatt demand basis and electric supply service is not
1698	1698	26 provided based on hourly pricing in the following manner:
1699	1699
1700	1700
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1705	1705
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1708	1708	HB5021 - 48 - LRB103 36729 LNS 66839 b
1709	1709	1 (1) If the amount of electricity used by the customer
1710	1710	2 during the billing period exceeds the amount of
1711	1711	3 electricity produced by the customer, then the electricity
1712	1712	4 provider shall charge the customer for the net electricity
1713	1713	5 supplied to and used by the customer as provided in
1714	1714	6 subsection (e-5) of this Section. The customer shall
1715	1715	7 remain responsible for all taxes, fees, and utility
1716	1716	8 delivery charges that would otherwise be applicable to the
1717	1717	9 net amount of electricity used by the customer.
1718	1718	10 (2) If the amount of electricity produced by a
1719	1719	11 customer during the billing period exceeds the amount of
1720	1720	12 electricity used by the customer during that billing
1721	1721	13 period, then the electricity provider supplying that
1722	1722	14 customer shall apply a 1:1 kilowatt-hour credit that
1723	1723	15 reflects the kilowatt-hour based charges in the customer's
1724	1724	16 electric service rate to a subsequent bill for service to
1725	1725	17 the customer for the net electricity supplied to the
1726	1726	18 electricity provider. The electricity provider shall
1727	1727	19 continue to carry over any excess kilowatt-hour credits
1728	1728	20 earned and apply those credits to subsequent billing
1729	1729	21 periods to offset any customer-generator consumption in
1730	1730	22 those billing periods until all credits are used or until
1731	1731	23 the end of the annualized period.
1732	1732	24 (3) At the end of the year or annualized over the
1733	1733	25 period that service is supplied by means of net metering,
1734	1734	26 or in the event that the retail customer terminates
1735	1735
1736	1736
1737	1737
1738	1738
1739	1739
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1741	1741
1742	1742
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1744	1744	HB5021 - 49 - LRB103 36729 LNS 66839 b
1745	1745	1 service with the electricity provider prior to the end of
1746	1746	2 the year or the annualized period, any remaining credits
1747	1747	3 in the customer's account shall expire.
1748	1748	4 (e-5) An electricity provider shall provide electric
1749	1749	5 service to eligible customers who utilize net metering at
1750	1750	6 non-discriminatory rates that are identical, with respect to
1751	1751	7 rate structure, retail rate components, and any monthly
1752	1752	8 charges, to the rates that the customer would be charged if not
1753	1753	9 a net metering customer. An electricity provider shall not
1754	1754	10 charge net metering customers any fee or charge or require
1755	1755	11 additional equipment, insurance, or any other requirements not
1756	1756	12 specifically authorized by interconnection standards
1757	1757	13 authorized by the Commission, unless the fee, charge, or other
1758	1758	14 requirement would apply to other similarly situated customers
1759	1759	15 who are not net metering customers. The customer will remain
1760	1760	16 responsible for all taxes, fees, and utility delivery charges
1761	1761	17 that would otherwise be applicable to the net amount of
1762	1762	18 electricity used by the customer. Subsections (c) through (e)
1763	1763	19 of this Section shall not be construed to prevent an
1764	1764	20 arms-length agreement between an electricity provider and an
1765	1765	21 eligible customer that sets forth different prices, terms, and
1766	1766	22 conditions for the provision of net metering service,
1767	1767	23 including, but not limited to, the provision of the
1768	1768	24 appropriate metering equipment for non-residential customers.
1769	1769	25 (f) Notwithstanding the requirements of subsections (c)
1770	1770	26 through (e-5) of this Section, an electricity provider must
1771	1771
1772	1772
1773	1773
1774	1774
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1777	1777
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1781	1781	1 require dual-channel metering for customers operating eligible
1782	1782	2 renewable electrical generating facilities to whom the
1783	1783	3 provisions of neither subsection (d), (d-5), nor (e) of this
1784	1784	4 Section apply. In such cases, electricity charges and credits
1785	1785	5 shall be determined as follows:
1786	1786	6 (1) The electricity provider shall assess and the
1787	1787	7 customer remains responsible for all taxes, fees, and
1788	1788	8 utility delivery charges that would otherwise be
1789	1789	9 applicable to the gross amount of kilowatt-hours supplied
1790	1790	10 to the eligible customer by the electricity provider.
1791	1791	11 (2) Each month that service is supplied by means of
1792	1792	12 dual-channel metering, the electricity provider shall
1793	1793	13 compensate the eligible customer for any excess
1794	1794	14 kilowatt-hour credits at the electricity provider's
1795	1795	15 avoided cost of electricity supply over the monthly period
1796	1796	16 or as otherwise specified by the terms of a power-purchase
1797	1797	17 agreement negotiated between the customer and electricity
1798	1798	18 provider.
1799	1799	19 (3) For all eligible net metering customers taking
1800	1800	20 service from an electricity provider under contracts or
1801	1801	21 tariffs employing hourly or time-of-use rates, any monthly
1802	1802	22 consumption of electricity shall be calculated according
1803	1803	23 to the terms of the contract or tariff to which the same
1804	1804	24 customer would be assigned to or be eligible for if the
1805	1805	25 customer was not a net metering customer. When those same
1806	1806	26 customer-generators are net generators during any discrete
1807	1807
1808	1808
1809	1809
1810	1810
1811	1811
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1813	1813
1814	1814
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1816	1816	HB5021 - 51 - LRB103 36729 LNS 66839 b
1817	1817	1 hourly or time-of-use period, the net kilowatt-hours
1818	1818	2 produced shall be valued at the same price per
1819	1819	3 kilowatt-hour as the electric service provider would
1820	1820	4 charge for retail kilowatt-hour sales during that same
1821	1821	5 time-of-use period.
1822	1822	6 (g) For purposes of federal and State laws providing
1823	1823	7 renewable energy credits or greenhouse gas credits, the
1824	1824	8 eligible customer shall be treated as owning and having title
1825	1825	9 to the renewable energy attributes, renewable energy credits,
1826	1826	10 and greenhouse gas emission credits related to any electricity
1827	1827	11 produced by the qualified generating unit. The electricity
1828	1828	12 provider may not condition participation in a net metering
1829	1829	13 program on the signing over of a customer's renewable energy
1830	1830	14 credits; provided, however, this subsection (g) shall not be
1831	1831	15 construed to prevent an arms-length agreement between an
1832	1832	16 electricity provider and an eligible customer that sets forth
1833	1833	17 the ownership or title of the credits.
1834	1834	18 (h) Within 120 days after the effective date of this
1835	1835	19 amendatory Act of the 95th General Assembly, the Commission
1836	1836	20 shall establish standards for net metering and, if the
1837	1837	21 Commission has not already acted on its own initiative,
1838	1838	22 standards for the interconnection of eligible renewable
1839	1839	23 generating equipment to the utility system. The
1840	1840	24 interconnection standards shall address any procedural
1841	1841	25 barriers, delays, and administrative costs associated with the
1842	1842	26 interconnection of customer-generation while ensuring the
1843	1843
1844	1844
1845	1845
1846	1846
1847	1847
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1849	1849
1850	1850
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1852	1852	HB5021 - 52 - LRB103 36729 LNS 66839 b
1853	1853	1 safety and reliability of the units and the electric utility
1854	1854	2 system. The Commission shall consider the Institute of
1855	1855	3 Electrical and Electronics Engineers (IEEE) Standard 1547 and
1856	1856	4 the issues of (i) reasonable and fair fees and costs, (ii)
1857	1857	5 clear timelines for major milestones in the interconnection
1858	1858	6 process, (iii) nondiscriminatory terms of agreement, and (iv)
1859	1859	7 any best practices for interconnection of distributed
1860	1860	8 generation.
1861	1861	9 (h-5) Within 90 days after the effective date of this
1862	1862	10 amendatory Act of the 102nd General Assembly, the Commission
1863	1863	11 shall:
1864	1864	12 (1) establish an Interconnection Working Group. The
1865	1865	13 working group shall include representatives from electric
1866	1866	14 utilities, developers of renewable electric generating
1867	1867	15 facilities, other industries that regularly apply for
1868	1868	16 interconnection with the electric utilities,
1869	1869	17 representatives of distributed generation customers, the
1870	1870	18 Commission Staff, and such other stakeholders with a
1871	1871	19 substantial interest in the topics addressed by the
1872	1872	20 Interconnection Working Group. The Interconnection Working
1873	1873	21 Group shall address at least the following issues:
1874	1874	22 (A) cost and best available technology for
1875	1875	23 interconnection and metering, including the
1876	1876	24 standardization and publication of standard costs;
1877	1877	25 (B) transparency, accuracy and use of the
1878	1878	26 distribution interconnection queue and hosting
1879	1879
1880	1880
1881	1881
1882	1882
1883	1883
1884	1884	HB5021 - 52 - LRB103 36729 LNS 66839 b
1885	1885
1886	1886
1887	1887	HB5021- 53 -LRB103 36729 LNS 66839 b HB5021 - 53 - LRB103 36729 LNS 66839 b
1888	1888	HB5021 - 53 - LRB103 36729 LNS 66839 b
1889	1889	1 capacity maps;
1890	1890	2 (C) distribution system upgrade cost avoidance
1891	1891	3 through use of advanced inverter functions;
1892	1892	4 (D) predictability of the queue management process
1893	1893	5 and enforcement of timelines;
1894	1894	6 (E) benefits and challenges associated with group
1895	1895	7 studies and cost sharing;
1896	1896	8 (F) minimum requirements for application to the
1897	1897	9 interconnection process and throughout the
1898	1898	10 interconnection process to avoid queue clogging
1899	1899	11 behavior;
1900	1900	12 (G) process and customer service for
1901	1901	13 interconnecting customers adopting distributed energy
1902	1902	14 resources, including energy storage;
1903	1903	15 (H) options for metering distributed energy
1904	1904	16 resources, including energy storage;
1905	1905	17 (I) interconnection of new technologies, including
1906	1906	18 smart inverters and energy storage;
1907	1907	19 (J) collect, share, and examine data on Level 1
1908	1908	20 interconnection costs, including cost and type of
1909	1909	21 upgrades required for interconnection, and use this
1910	1910	22 data to inform the final standardized cost of Level 1
1911	1911	23 interconnection; and
1912	1912	24 (K) such other technical, policy, and tariff
1913	1913	25 issues related to and affecting interconnection
1914	1914	26 performance and customer service as determined by the
1915	1915
1916	1916
1917	1917
1918	1918
1919	1919
1920	1920	HB5021 - 53 - LRB103 36729 LNS 66839 b
1921	1921
1922	1922
1923	1923	HB5021- 54 -LRB103 36729 LNS 66839 b HB5021 - 54 - LRB103 36729 LNS 66839 b
1924	1924	HB5021 - 54 - LRB103 36729 LNS 66839 b
1925	1925	1 Interconnection Working Group.
1926	1926	2 The Commission may create subcommittees of the
1927	1927	3 Interconnection Working Group to focus on specific issues
1928	1928	4 of importance, as appropriate. The Interconnection Working
1929	1929	5 Group shall report to the Commission on recommended
1930	1930	6 improvements to interconnection rules and tariffs and
1931	1931	7 policies as determined by the Interconnection Working
1932	1932	8 Group at least every 6 months. Such reports shall include
1933	1933	9 consensus recommendations of the Interconnection Working
1934	1934	10 Group and, if applicable, additional recommendations for
1935	1935	11 which consensus was not reached. The Commission shall use
1936	1936	12 the report from the Interconnection Working Group to
1937	1937	13 determine whether processes should be commenced to
1938	1938	14 formally codify or implement the recommendations;
1939	1939	15 (2) create or contract for an Ombudsman to resolve
1940	1940	16 interconnection disputes through non-binding arbitration.
1941	1941	17 The Ombudsman may be paid in full or in part through fees
1942	1942	18 levied on the initiators of the dispute; and
1943	1943	19 (3) determine a single standardized cost for Level 1
1944	1944	20 interconnections, which shall not exceed $200.
1945	1945	21 (i) All electricity providers shall begin to offer net
1946	1946	22 metering no later than April 1, 2008.
1947	1947	23 (j) An electricity provider shall provide net metering to
1948	1948	24 eligible customers according to subsections (d), (d-5), and
1949	1949	25 (e). Eligible renewable electrical generating facilities for
1950	1950	26 which eligible customers registered for net metering before
1951	1951
1952	1952
1953	1953
1954	1954
1955	1955
1956	1956	HB5021 - 54 - LRB103 36729 LNS 66839 b
1957	1957
1958	1958
1959	1959	HB5021- 55 -LRB103 36729 LNS 66839 b HB5021 - 55 - LRB103 36729 LNS 66839 b
1960	1960	HB5021 - 55 - LRB103 36729 LNS 66839 b
1961	1961	1 January 1, 2025 shall continue to receive net metering
1962	1962	2 services according to subsections (d), (d-5), and (e) of this
1963	1963	3 Section for the lifetime of the system, regardless of whether
1964	1964	4 those retail customers change electricity providers or whether
1965	1965	5 the retail customer benefiting from the system changes. On and
1966	1966	6 after January 1, 2025, any eligible customer that applies for
1967	1967	7 net metering and previously would have qualified under
1968	1968	8 subsections (d), (d-5), or (e) shall only be eligible for net
1969	1969	9 metering as described in subsection (n).
1970	1970	10 (k) Each electricity provider shall maintain records and
1971	1971	11 report annually to the Commission the total number of net
1972	1972	12 metering customers served by the provider, as well as the
1973	1973	13 type, capacity, and energy sources of the generating systems
1974	1974	14 used by the net metering customers. Nothing in this Section
1975	1975	15 shall limit the ability of an electricity provider to request
1976	1976	16 the redaction of information deemed by the Commission to be
1977	1977	17 confidential business information.
1978	1978	18 (l)(1) Notwithstanding the definition of "eligible
1979	1979	19 customer" in item (ii) of subsection (b) of this Section, each
1980	1980	20 electricity provider shall allow net metering as set forth in
1981	1981	21 this subsection (l) and for the following projects, provided
1982	1982	22 that only electric utilities serving more than 200,000
1983	1983	23 customers as of January 1, 2021 shall provide net metering for
1984	1984	24 projects that are eligible for subparagraph (C) of this
1985	1985	25 paragraph (1) and have energized after the effective date of
1986	1986	26 this amendatory Act of the 102nd General Assembly:
1987	1987
1988	1988
1989	1989
1990	1990
1991	1991
1992	1992	HB5021 - 55 - LRB103 36729 LNS 66839 b
1993	1993
1994	1994
1995	1995	HB5021- 56 -LRB103 36729 LNS 66839 b HB5021 - 56 - LRB103 36729 LNS 66839 b
1996	1996	HB5021 - 56 - LRB103 36729 LNS 66839 b
1997	1997	1 (A) properties owned or leased by multiple customers
1998	1998	2 that contribute to the operation of an eligible renewable
1999	1999	3 electrical generating facility through an ownership or
2000	2000	4 leasehold interest of at least 200 watts in such facility,
2001	2001	5 such as a community-owned wind project, a community-owned
2002	2002	6 biomass project, a community-owned solar project, or a
2003	2003	7 community methane digester processing livestock waste from
2004	2004	8 multiple sources, provided that the facility is also
2005	2005	9 located within the utility's service territory;
2006	2006	10 (B) individual units, apartments, or properties
2007	2007	11 located in a single building that are owned or leased by
2008	2008	12 multiple customers and collectively served by a common
2009	2009	13 eligible renewable electrical generating facility, such as
2010	2010	14 an office or apartment building, a shopping center or
2011	2011	15 strip mall served by photovoltaic panels on the roof; and
2012	2012	16 (C) subscriptions to community renewable generation
2013	2013	17 projects, including community renewable generation
2014	2014	18 projects on the customer's side of the billing meter of a
2015	2015	19 host facility and partially used for the customer's own
2016	2016	20 load.
2017	2017	21 In addition, the nameplate capacity of the eligible
2018	2018	22 renewable electric generating facility that serves the demand
2019	2019	23 of the properties, units, or apartments identified in
2020	2020	24 paragraphs (1) and (2) of this subsection (l) shall not exceed
2021	2021	25 5,000 kilowatts in nameplate capacity in total. Any eligible
2022	2022	26 renewable electrical generating facility or community
2023	2023
2024	2024
2025	2025
2026	2026
2027	2027
2028	2028	HB5021 - 56 - LRB103 36729 LNS 66839 b
2029	2029
2030	2030
2031	2031	HB5021- 57 -LRB103 36729 LNS 66839 b HB5021 - 57 - LRB103 36729 LNS 66839 b
2032	2032	HB5021 - 57 - LRB103 36729 LNS 66839 b
2033	2033	1 renewable generation project that is powered by photovoltaic
2034	2034	2 electric energy and installed after the effective date of this
2035	2035	3 amendatory Act of the 99th General Assembly must be installed
2036	2036	4 by a qualified person in compliance with the requirements of
2037	2037	5 Section 16-128A of the Public Utilities Act and any rules or
2038	2038	6 regulations adopted thereunder.
2039	2039	7 (2) Notwithstanding anything to the contrary, an
2040	2040	8 electricity provider shall provide credits for the electricity
2041	2041	9 produced by the projects described in paragraph (1) of this
2042	2042	10 subsection (l). The electricity provider shall provide credits
2043	2043	11 that include at least energy supply, capacity, transmission,
2044	2044	12 and, if applicable, the purchased energy adjustment on the
2045	2045	13 subscriber's monthly bill equal to the subscriber's share of
2046	2046	14 the production of electricity from the project, as determined
2047	2047	15 by paragraph (3) of this subsection (l). For customers with
2048	2048	16 transmission or capacity charges not charged on a
2049	2049	17 kilowatt-hour basis, the electricity provider shall prepare a
2050	2050	18 reasonable approximation of the kilowatt-hour equivalent value
2051	2051	19 and provide that value as a monetary credit. The electricity
2052	2052	20 provider shall submit these approximation methodologies to the
2053	2053	21 Commission for review, modification, and approval.
2054	2054	22 Notwithstanding anything to the contrary, customers on payment
2055	2055	23 plans or participating in budget billing programs shall have
2056	2056	24 credits applied on a monthly basis.
2057	2057	25 (3) Notwithstanding anything to the contrary and
2058	2058	26 regardless of whether a subscriber to an eligible community
2059	2059
2060	2060
2061	2061
2062	2062
2063	2063
2064	2064	HB5021 - 57 - LRB103 36729 LNS 66839 b
2065	2065
2066	2066
2067	2067	HB5021- 58 -LRB103 36729 LNS 66839 b HB5021 - 58 - LRB103 36729 LNS 66839 b
2068	2068	HB5021 - 58 - LRB103 36729 LNS 66839 b
2069	2069	1 renewable generation project receives power and energy service
2070	2070	2 from the electric utility or an alternative retail electric
2071	2071	3 supplier, for projects eligible under paragraph (C) of
2072	2072	4 subparagraph (1) of this subsection (l), electric utilities
2073	2073	5 serving more than 200,000 customers as of January 1, 2021
2074	2074	6 shall provide the monetary credits to a subscriber's
2075	2075	7 subsequent bill for the electricity produced by community
2076	2076	8 renewable generation projects. The electric utility shall
2077	2077	9 provide monetary credits to a subscriber's subsequent bill at
2078	2078	10 the utility's total price to compare equal to the subscriber's
2079	2079	11 share of the production of electricity from the project, as
2080	2080	12 determined by paragraph (5) of this subsection (l). For the
2081	2081	13 purposes of this subsection, "total price to compare" means
2082	2082	14 the rate or rates published by the Illinois Commerce
2083	2083	15 Commission for energy supply for eligible customers receiving
2084	2084	16 supply service from the electric utility, and shall include
2085	2085	17 energy, capacity, transmission, and the purchased energy
2086	2086	18 adjustment. Notwithstanding anything to the contrary,
2087	2087	19 customers on payment plans or participating in budget billing
2088	2088	20 programs shall have credits applied on a monthly basis. Any
2089	2089	21 applicable credit or reduction in load obligation from the
2090	2090	22 production of the community renewable generating projects
2091	2091	23 receiving a credit under this subsection shall be credited to
2092	2092	24 the electric utility to offset the cost of providing the
2093	2093	25 credit. To the extent that the credit or load obligation
2094	2094	26 reduction does not completely offset the cost of providing the
2095	2095
2096	2096
2097	2097
2098	2098
2099	2099
2100	2100	HB5021 - 58 - LRB103 36729 LNS 66839 b
2101	2101
2102	2102
2103	2103	HB5021- 59 -LRB103 36729 LNS 66839 b HB5021 - 59 - LRB103 36729 LNS 66839 b
2104	2104	HB5021 - 59 - LRB103 36729 LNS 66839 b
2105	2105	1 credit to subscribers of community renewable generation
2106	2106	2 projects as described in this subsection, the electric utility
2107	2107	3 may recover the remaining costs through its Multi-Year Rate
2108	2108	4 Plan. All electric utilities serving 200,000 or fewer
2109	2109	5 customers as of January 1, 2021 shall only provide the
2110	2110	6 monetary credits to a subscriber's subsequent bill for the
2111	2111	7 electricity produced by community renewable generation
2112	2112	8 projects if the subscriber receives power and energy service
2113	2113	9 from the electric utility. Alternative retail electric
2114	2114	10 suppliers providing power and energy service to a subscriber
2115	2115	11 located within the service territory of an electric utility
2116	2116	12 not subject to Sections 16-108.18 and 16-118 shall provide the
2117	2117	13 monetary credits to the subscriber's subsequent bill for the
2118	2118	14 electricity produced by community renewable generation
2119	2119	15 projects.
2120	2120	16 (4) If requested by the owner or operator of a community
2121	2121	17 renewable generating project, an electric utility serving more
2122	2122	18 than 200,000 customers as of January 1, 2021 shall enter into a
2123	2123	19 net crediting agreement with the owner or operator to include
2124	2124	20 a subscriber's subscription fee on the subscriber's monthly
2125	2125	21 electric bill and provide the subscriber with a net credit
2126	2126	22 equivalent to the total bill credit value for that generation
2127	2127	23 period minus the subscription fee, provided the subscription
2128	2128	24 fee is structured as a fixed percentage of bill credit value.
2129	2129	25 The net crediting agreement shall set forth payment terms from
2130	2130	26 the electric utility to the owner or operator of the community
2131	2131
2132	2132
2133	2133
2134	2134
2135	2135
2136	2136	HB5021 - 59 - LRB103 36729 LNS 66839 b
2137	2137
2138	2138
2139	2139	HB5021- 60 -LRB103 36729 LNS 66839 b HB5021 - 60 - LRB103 36729 LNS 66839 b
2140	2140	HB5021 - 60 - LRB103 36729 LNS 66839 b
2141	2141	1 renewable generating project, and the electric utility may
2142	2142	2 charge a net crediting fee to the owner or operator of a
2143	2143	3 community renewable generating project that may not exceed 2%
2144	2144	4 of the bill credit value. Notwithstanding anything to the
2145	2145	5 contrary, an electric utility serving 200,000 customers or
2146	2146	6 fewer as of January 1, 2021 shall not be obligated to enter
2147	2147	7 into a net crediting agreement with the owner or operator of a
2148	2148	8 community renewable generating project.
2149	2149	9 (5) For the purposes of facilitating net metering, the
2150	2150	10 owner or operator of the eligible renewable electrical
2151	2151	11 generating facility or community renewable generation project
2152	2152	12 shall be responsible for determining the amount of the credit
2153	2153	13 that each customer or subscriber participating in a project
2154	2154	14 under this subsection (l) is to receive in the following
2155	2155	15 manner:
2156	2156	16 (A) The owner or operator shall, on a monthly basis,
2157	2157	17 provide to the electric utility the kilowatthours of
2158	2158	18 generation attributable to each of the utility's retail
2159	2159	19 customers and subscribers participating in projects under
2160	2160	20 this subsection (l) in accordance with the customer's or
2161	2161	21 subscriber's share of the eligible renewable electric
2162	2162	22 generating facility's or community renewable generation
2163	2163	23 project's output of power and energy for such month. The
2164	2164	24 owner or operator shall electronically transmit such
2165	2165	25 calculations and associated documentation to the electric
2166	2166	26 utility, in a format or method set forth in the applicable
2167	2167
2168	2168
2169	2169
2170	2170
2171	2171
2172	2172	HB5021 - 60 - LRB103 36729 LNS 66839 b
2173	2173
2174	2174
2175	2175	HB5021- 61 -LRB103 36729 LNS 66839 b HB5021 - 61 - LRB103 36729 LNS 66839 b
2176	2176	HB5021 - 61 - LRB103 36729 LNS 66839 b
2177	2177	1 tariff, on a monthly basis so that the electric utility
2178	2178	2 can reflect the monetary credits on customers' and
2179	2179	3 subscribers' electric utility bills. The electric utility
2180	2180	4 shall be permitted to revise its tariffs to implement the
2181	2181	5 provisions of this amendatory Act of the 102nd General
2182	2182	6 Assembly. The owner or operator shall separately provide
2183	2183	7 the electric utility with the documentation detailing the
2184	2184	8 calculations supporting the credit in the manner set forth
2185	2185	9 in the applicable tariff.
2186	2186	10 (B) For those participating customers and subscribers
2187	2187	11 who receive their energy supply from an alternative retail
2188	2188	12 electric supplier, the electric utility shall remit to the
2189	2189	13 applicable alternative retail electric supplier the
2190	2190	14 information provided under subparagraph (A) of this
2191	2191	15 paragraph (3) for such customers and subscribers in a
2192	2192	16 manner set forth in such alternative retail electric
2193	2193	17 supplier's net metering program, or as otherwise agreed
2194	2194	18 between the utility and the alternative retail electric
2195	2195	19 supplier. The alternative retail electric supplier shall
2196	2196	20 then submit to the utility the amount of the charges for
2197	2197	21 power and energy to be applied to such customers and
2198	2198	22 subscribers, including the amount of the credit associated
2199	2199	23 with net metering.
2200	2200	24 (C) A participating customer or subscriber may provide
2201	2201	25 authorization as required by applicable law that directs
2202	2202	26 the electric utility to submit information to the owner or
2203	2203
2204	2204
2205	2205
2206	2206
2207	2207
2208	2208	HB5021 - 61 - LRB103 36729 LNS 66839 b
2209	2209
2210	2210
2211	2211	HB5021- 62 -LRB103 36729 LNS 66839 b HB5021 - 62 - LRB103 36729 LNS 66839 b
2212	2212	HB5021 - 62 - LRB103 36729 LNS 66839 b
2213	2213	1 operator of the eligible renewable electrical generating
2214	2214	2 facility or community renewable generation project to
2215	2215	3 which the customer or subscriber has an ownership or
2216	2216	4 leasehold interest or a subscription. Such information
2217	2217	5 shall be limited to the components of the net metering
2218	2218	6 credit calculated under this subsection (l), including the
2219	2219	7 bill credit rate, total kilowatthours, and total monetary
2220	2220	8 credit value applied to the customer's or subscriber's
2221	2221	9 bill for the monthly billing period.
2222	2222	10 (l-5) Within 90 days after the effective date of this
2223	2223	11 amendatory Act of the 102nd General Assembly, each electric
2224	2224	12 utility subject to this Section shall file a tariff or tariffs
2225	2225	13 to implement the provisions of subsection (l) of this Section,
2226	2226	14 which shall, consistent with the provisions of subsection (l),
2227	2227	15 describe the terms and conditions under which owners or
2228	2228	16 operators of qualifying properties, units, or apartments may
2229	2229	17 participate in net metering. The Commission shall approve, or
2230	2230	18 approve with modification, the tariff within 120 days after
2231	2231	19 the effective date of this amendatory Act of the 102nd General
2232	2232	20 Assembly.
2233	2233	21 (m) Nothing in this Section shall affect the right of an
2234	2234	22 electricity provider to continue to provide, or the right of a
2235	2235	23 retail customer to continue to receive service pursuant to a
2236	2236	24 contract for electric service between the electricity provider
2237	2237	25 and the retail customer in accordance with the prices, terms,
2238	2238	26 and conditions provided for in that contract. Either the
2239	2239
2240	2240
2241	2241
2242	2242
2243	2243
2244	2244	HB5021 - 62 - LRB103 36729 LNS 66839 b
2245	2245
2246	2246
2247	2247	HB5021- 63 -LRB103 36729 LNS 66839 b HB5021 - 63 - LRB103 36729 LNS 66839 b
2248	2248	HB5021 - 63 - LRB103 36729 LNS 66839 b
2249	2249	1 electricity provider or the customer may require compliance
2250	2250	2 with the prices, terms, and conditions of the contract.
2251	2251	3 (n) On and after January 1, 2025, the net metering
2252	2252	4 services described in subsections (d), (d-5), and (e) of this
2253	2253	5 Section shall no longer be offered, except as to those
2254	2254	6 eligible renewable electrical generating facilities for which
2255	2255	7 retail customers are receiving net metering service under
2256	2256	8 these subsections at the time the net metering services under
2257	2257	9 those subsections are no longer offered; those systems shall
2258	2258	10 continue to receive net metering services described in
2259	2259	11 subsections (d), (d-5), and (e) of this Section for the
2260	2260	12 lifetime of the system, regardless of if those retail
2261	2261	13 customers change electricity providers or whether the retail
2262	2262	14 customer benefiting from the system changes. The electric
2263	2263	15 utility serving more than 200,000 customers as of January 1,
2264	2264	16 2021 is responsible for ensuring the billing credits continue
2265	2265	17 without lapse for the lifetime of systems, as required in
2266	2266	18 subsection (o). Those retail customers that begin taking net
2267	2267	19 metering service after the date that net metering services are
2268	2268	20 no longer offered under such subsections shall be subject to
2269	2269	21 the provisions set forth in the following paragraphs (1)
2270	2270	22 through (3) of this subsection (n):
2271	2271	23 (1) An electricity provider shall charge or credit for
2272	2272	24 the net electricity supplied to eligible customers or
2273	2273	25 provided by eligible customers whose electric supply
2274	2274	26 service is not provided based on hourly pricing in the
2275	2275
2276	2276
2277	2277
2278	2278
2279	2279
2280	2280	HB5021 - 63 - LRB103 36729 LNS 66839 b
2281	2281
2282	2282
2283	2283	HB5021- 64 -LRB103 36729 LNS 66839 b HB5021 - 64 - LRB103 36729 LNS 66839 b
2284	2284	HB5021 - 64 - LRB103 36729 LNS 66839 b
2285	2285	1 following manner:
2286	2286	2 (A) If the amount of electricity used by the
2287	2287	3 customer during the monthly billing period exceeds the
2288	2288	4 amount of electricity produced by the customer, then
2289	2289	5 the electricity provider shall charge the customer for
2290	2290	6 the net kilowatt-hour based electricity charges
2291	2291	7 reflected in the customer's electric service rate
2292	2292	8 supplied to and used by the customer as provided in
2293	2293	9 paragraph (3) of this subsection (n).
2294	2294	10 (B) If the amount of electricity produced by a
2295	2295	11 customer during the monthly billing period exceeds the
2296	2296	12 amount of electricity used by the customer during that
2297	2297	13 billing period, then the electricity provider
2298	2298	14 supplying that customer shall apply a 1:1
2299	2299	15 kilowatt-hour energy or monetary credit kilowatt-hour
2300	2300	16 supply charges to the customer's subsequent bill. The
2301	2301	17 customer shall choose between 1:1 kilowatt-hour or
2302	2302	18 monetary credit at the time of application. For the
2303	2303	19 purposes of this subsection, "kilowatt-hour supply
2304	2304	20 charges" means the kilowatt-hour equivalent values for
2305	2305	21 energy, capacity, transmission, and the purchased
2306	2306	22 energy adjustment, if applicable. Notwithstanding
2307	2307	23 anything to the contrary, customers on payment plans
2308	2308	24 or participating in budget billing programs shall have
2309	2309	25 credits applied on a monthly basis. The electricity
2310	2310	26 provider shall continue to carry over any excess
2311	2311
2312	2312
2313	2313
2314	2314
2315	2315
2316	2316	HB5021 - 64 - LRB103 36729 LNS 66839 b
2317	2317
2318	2318
2319	2319	HB5021- 65 -LRB103 36729 LNS 66839 b HB5021 - 65 - LRB103 36729 LNS 66839 b
2320	2320	HB5021 - 65 - LRB103 36729 LNS 66839 b
2321	2321	1 kilowatt-hour or monetary energy credits earned and
2322	2322	2 apply those credits to subsequent billing periods. For
2323	2323	3 customers with transmission or capacity charges not
2324	2324	4 charged on a kilowatt-hour basis, the electricity
2325	2325	5 provider shall prepare a reasonable approximation of
2326	2326	6 the kilowatt-hour equivalent value and provide that
2327	2327	7 value as a monetary credit. The electricity provider
2328	2328	8 shall submit these approximation methodologies to the
2329	2329	9 Commission for review, modification, and approval.
2330	2330	10 (C) (Blank).
2331	2331	11 (2) An electricity provider shall charge or credit for
2332	2332	12 the net electricity supplied to eligible customers or
2333	2333	13 provided by eligible customers whose electric supply
2334	2334	14 service is provided based on hourly pricing in the
2335	2335	15 following manner:
2336	2336	16 (A) If the amount of electricity used by the
2337	2337	17 customer during any hourly period exceeds the amount
2338	2338	18 of electricity produced by the customer, then the
2339	2339	19 electricity provider shall charge the customer for the
2340	2340	20 net electricity supplied to and used by the customer
2341	2341	21 as provided in paragraph (3) of this subsection (n).
2342	2342	22 (B) If the amount of electricity produced by a
2343	2343	23 customer during any hourly period exceeds the amount
2344	2344	24 of electricity used by the customer during that hourly
2345	2345	25 period, the energy provider shall calculate an energy
2346	2346	26 credit for the net kilowatt-hours produced in such
2347	2347
2348	2348
2349	2349
2350	2350
2351	2351
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2353	2353
2354	2354
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2356	2356	HB5021 - 66 - LRB103 36729 LNS 66839 b
2357	2357	1 period, and shall apply that credit as a monetary
2358	2358	2 credit to the customer's subsequent bill. The value of
2359	2359	3 the energy credit shall be calculated using the same
2360	2360	4 price per kilowatt-hour as the electric service
2361	2361	5 provider would charge for kilowatt-hour energy sales
2362	2362	6 during that same hourly period and shall also include
2363	2363	7 values for capacity and transmission. For customers
2364	2364	8 with transmission or capacity charges not charged on a
2365	2365	9 kilowatt-hour basis, the electricity provider shall
2366	2366	10 prepare a reasonable approximation of the
2367	2367	11 kilowatt-hour equivalent value and provide that value
2368	2368	12 as a monetary credit. The electricity provider shall
2369	2369	13 submit these approximation methodologies to the
2370	2370	14 Commission for review, modification, and approval.
2371	2371	15 Notwithstanding anything to the contrary, customers on
2372	2372	16 payment plans or participating in budget billing
2373	2373	17 programs shall have credits applied on a monthly
2374	2374	18 basis.
2375	2375	19 (3) An electricity provider shall provide electric
2376	2376	20 service to eligible customers who utilize net metering at
2377	2377	21 non-discriminatory rates that are identical, with respect
2378	2378	22 to rate structure, retail rate components, and any monthly
2379	2379	23 charges, to the rates that the customer would be charged
2380	2380	24 if not a net metering customer. An electricity provider
2381	2381	25 shall charge the customer for the net electricity supplied
2382	2382	26 to and used by the customer according to the terms of the
2383	2383
2384	2384
2385	2385
2386	2386
2387	2387
2388	2388	HB5021 - 66 - LRB103 36729 LNS 66839 b
2389	2389
2390	2390
2391	2391	HB5021- 67 -LRB103 36729 LNS 66839 b HB5021 - 67 - LRB103 36729 LNS 66839 b
2392	2392	HB5021 - 67 - LRB103 36729 LNS 66839 b
2393	2393	1 contract or tariff to which the same customer would be
2394	2394	2 assigned or be eligible for if the customer was not a net
2395	2395	3 metering customer. An electricity provider shall not
2396	2396	4 charge net metering customers any fee or charge or require
2397	2397	5 additional equipment, insurance, or any other requirements
2398	2398	6 not specifically authorized by interconnection standards
2399	2399	7 authorized by the Commission, unless the fee, charge, or
2400	2400	8 other requirement would apply to other similarly situated
2401	2401	9 customers who are not net metering customers. The customer
2402	2402	10 remains responsible for the gross amount of delivery
2403	2403	11 services charges, supply-related charges that are kilowatt
2404	2404	12 based, and all taxes and fees related to such charges. The
2405	2405	13 customer also remains responsible for all taxes and fees
2406	2406	14 that would otherwise be applicable to the net amount of
2407	2407	15 electricity used by the customer. Paragraphs (1) and (2)
2408	2408	16 of this subsection (n) shall not be construed to prevent
2409	2409	17 an arms-length agreement between an electricity provider
2410	2410	18 and an eligible customer that sets forth different prices,
2411	2411	19 terms, and conditions for the provision of net metering
2412	2412	20 service, including, but not limited to, the provision of
2413	2413	21 the appropriate metering equipment for non-residential
2414	2414	22 customers. Nothing in this paragraph (3) shall be
2415	2415	23 interpreted to mandate that a utility that is only
2416	2416	24 required to provide delivery services to a given customer
2417	2417	25 must also sell electricity to such customer.
2418	2418	26 (o) Within 90 days after the effective date of this
2419	2419
2420	2420
2421	2421
2422	2422
2423	2423
2424	2424	HB5021 - 67 - LRB103 36729 LNS 66839 b
2425	2425
2426	2426
2427	2427	HB5021- 68 -LRB103 36729 LNS 66839 b HB5021 - 68 - LRB103 36729 LNS 66839 b
2428	2428	HB5021 - 68 - LRB103 36729 LNS 66839 b
2429	2429	1 amendatory Act of the 102nd General Assembly, each electric
2430	2430	2 utility subject to this Section shall file a tariff, which
2431	2431	3 shall, consistent with the provisions of this Section, propose
2432	2432	4 the terms and conditions under which a customer may
2433	2433	5 participate in net metering. The tariff for electric utilities
2434	2434	6 serving more than 200,000 customers as of January 1, 2021
2435	2435	7 shall also provide a streamlined and transparent bill
2436	2436	8 crediting system for net metering to be managed by the
2437	2437	9 electric utilities. The terms and conditions shall include,
2438	2438	10 but are not limited to, that an electric utility shall manage
2439	2439	11 and maintain billing of net metering credits and charges
2440	2440	12 regardless of if the eligible customer takes net metering
2441	2441	13 under an electric utility or alternative retail electric
2442	2442	14 supplier. The electric utility serving more than 200,000
2443	2443	15 customers as of January 1, 2021 shall process and approve all
2444	2444	16 net metering applications, even if an eligible customer is
2445	2445	17 served by an alternative retail electric supplier; and the
2446	2446	18 utility shall forward application approval to the appropriate
2447	2447	19 alternative retail electric supplier. Eligibility for net
2448	2448	20 metering shall remain with the owner of the utility billing
2449	2449	21 address such that, if an eligible renewable electrical
2450	2450	22 generating facility changes ownership, the net metering
2451	2451	23 eligibility transfers to the new owner. The electric utility
2452	2452	24 serving more than 200,000 customers as of January 1, 2021
2453	2453	25 shall manage net metering billing for eligible customers to
2454	2454	26 ensure full crediting occurs on electricity bills, including,
2455	2455
2456	2456
2457	2457
2458	2458
2459	2459
2460	2460	HB5021 - 68 - LRB103 36729 LNS 66839 b
2461	2461
2462	2462
2463	2463	HB5021- 69 -LRB103 36729 LNS 66839 b HB5021 - 69 - LRB103 36729 LNS 66839 b
2464	2464	HB5021 - 69 - LRB103 36729 LNS 66839 b
2465	2465	1 but not limited to, ensuring net metering crediting begins
2466	2466	2 upon commercial operation date, net metering billing transfers
2467	2467	3 immediately if an eligible customer switches from an electric
2468	2468	4 utility to alternative retail electric supplier or vice versa,
2469	2469	5 and net metering billing transfers between ownership of a
2470	2470	6 valid billing address. All transfers referenced in the
2471	2471	7 preceding sentence shall include transfer of all banked
2472	2472	8 credits. All electric utilities serving 200,000 or fewer
2473	2473	9 customers as of January 1, 2021 shall manage net metering
2474	2474	10 billing for eligible customers receiving power and energy
2475	2475	11 service from the electric utility to ensure full crediting
2476	2476	12 occurs on electricity bills, ensuring net metering crediting
2477	2477	13 begins upon commercial operation date, net metering billing
2478	2478	14 transfers immediately if an eligible customer switches from an
2479	2479	15 electric utility to alternative retail electric supplier or
2480	2480	16 vice versa, and net metering billing transfers between
2481	2481	17 ownership of a valid billing address. Alternative retail
2482	2482	18 electric suppliers providing power and energy service to
2483	2483	19 eligible customers located within the service territory of an
2484	2484	20 electric utility serving 200,000 or fewer customers as of
2485	2485	21 January 1, 2021 shall manage net metering billing for eligible
2486	2486	22 customers to ensure full crediting occurs on electricity
2487	2487	23 bills, including, but not limited to, ensuring net metering
2488	2488	24 crediting begins upon commercial operation date, net metering
2489	2489	25 billing transfers immediately if an eligible customer switches
2490	2490	26 from an electric utility to alternative retail electric
2491	2491
2492	2492
2493	2493
2494	2494
2495	2495
2496	2496	HB5021 - 69 - LRB103 36729 LNS 66839 b
2497	2497
2498	2498
2499	2499	HB5021- 70 -LRB103 36729 LNS 66839 b HB5021 - 70 - LRB103 36729 LNS 66839 b
2500	2500	HB5021 - 70 - LRB103 36729 LNS 66839 b
2501	2501	1 supplier or vice versa, and net metering billing transfers
2502	2502	2 between ownership of a valid billing address.
2503	2503	3 (Source: P.A. 102-662, eff. 9-15-21.)
2504	2504	4 (220 ILCS 5/17-500)
2505	2505	5 Sec. 17-500. Jurisdiction. Except as provided in the
2506	2506	6 Electric Supplier Act, the Illinois Municipal Code, the
2507	2507	7 Municipal and Cooperative Electric Utility Planning and
2508	2508	8 Transparency Act, and this Article XVII, the Commission, or
2509	2509	9 any other agency or subdivision thereof of the State of
2510	2510	10 Illinois or any private entity shall have no jurisdiction over
2511	2511	11 any electric cooperative or municipal system regardless of
2512	2512	12 whether any election or elections as provided for herein have
2513	2513	13 been made, and all control regarding an electric cooperative
2514	2514	14 or municipal system shall be vested in the electric
2515	2515	15 cooperative's board of directors or trustees or the applicable
2516	2516	16 governing body of the municipal system.
2517	2517	17 (Source: P.A. 90-561, eff. 12-16-97.)
2518	2518	18 Section 60. The Eminent Domain Act is amended by changing
2519	2519	19 Section 5-5-5 as follows:
2520	2520	20 (735 ILCS 30/5-5-5)
2521	2521	21 Sec. 5-5-5. Exercise of the power of eminent domain;
2522	2522	22 public use; blight.
2523	2523	23 (a) In addition to all other limitations and requirements,
2524	2524
2525	2525
2526	2526
2527	2527
2528	2528
2529	2529	HB5021 - 70 - LRB103 36729 LNS 66839 b
2530	2530
2531	2531
2532	2532	HB5021- 71 -LRB103 36729 LNS 66839 b HB5021 - 71 - LRB103 36729 LNS 66839 b
2533	2533	HB5021 - 71 - LRB103 36729 LNS 66839 b
2534	2534	1 a condemning authority may not take or damage property by the
2535	2535	2 exercise of the power of eminent domain unless it is for a
2536	2536	3 public use, as set forth in this Section.
2537	2537	4 (a-5) Subsections (b), (c), (d), (e), and (f) of this
2538	2538	5 Section do not apply to the acquisition of property under the
2539	2539	6 O'Hare Modernization Act. A condemning authority may exercise
2540	2540	7 the power of eminent domain for the acquisition or damaging of
2541	2541	8 property under the O'Hare Modernization Act as provided for by
2542	2542	9 law in effect prior to the effective date of this Act.
2543	2543	10 (a-10) Subsections (b), (c), (d), (e), and (f) of this
2544	2544	11 Section do not apply to the acquisition or damaging of
2545	2545	12 property in furtherance of the goals and objectives of an
2546	2546	13 existing tax increment allocation redevelopment plan. A
2547	2547	14 condemning authority may exercise the power of eminent domain
2548	2548	15 for the acquisition of property in furtherance of an existing
2549	2549	16 tax increment allocation redevelopment plan as provided for by
2550	2550	17 law in effect prior to the effective date of this Act.
2551	2551	18 As used in this subsection, "existing tax increment
2552	2552	19 allocation redevelopment plan" means a redevelopment plan that
2553	2553	20 was adopted under the Tax Increment Allocation Redevelopment
2554	2554	21 Act (Article 11, Division 74.4 of the Illinois Municipal Code)
2555	2555	22 prior to April 15, 2006 and for which property assembly costs
2556	2556	23 were, before that date, included as a budget line item in the
2557	2557	24 plan or described in the narrative portion of the plan as part
2558	2558	25 of the redevelopment project, but does not include (i) any
2559	2559	26 additional area added to the redevelopment project area on or
2560	2560
2561	2561
2562	2562
2563	2563
2564	2564
2565	2565	HB5021 - 71 - LRB103 36729 LNS 66839 b
2566	2566
2567	2567
2568	2568	HB5021- 72 -LRB103 36729 LNS 66839 b HB5021 - 72 - LRB103 36729 LNS 66839 b
2569	2569	HB5021 - 72 - LRB103 36729 LNS 66839 b
2570	2570	1 after April 15, 2006, (ii) any subsequent extension of the
2571	2571	2 completion date of a redevelopment plan beyond the estimated
2572	2572	3 completion date established in that plan prior to April 15,
2573	2573	4 2006, (iii) any acquisition of property in a conservation area
2574	2574	5 for which the condemnation complaint is filed more than 12
2575	2575	6 years after the effective date of this Act, or (iv) any
2576	2576	7 acquisition of property in an industrial park conservation
2577	2577	8 area.
2578	2578	9 As used in this subsection, "conservation area" and
2579	2579	10 "industrial park conservation area" have the same meanings as
2580	2580	11 under Section 11-74.4-3 of the Illinois Municipal Code.
2581	2581	12 (b) If the exercise of eminent domain authority is to
2582	2582	13 acquire property for public ownership and control, then the
2583	2583	14 condemning authority must prove that (i) the acquisition of
2584	2584	15 the property is necessary for a public purpose and (ii) the
2585	2585	16 acquired property will be owned and controlled by the
2586	2586	17 condemning authority or another governmental entity.
2587	2587	18 (c) Except when the acquisition is governed by subsection
2588	2588	19 (b) or is primarily for one of the purposes specified in
2589	2589	20 subsection (d), (e), or (f) and the condemning authority
2590	2590	21 elects to proceed under one of those subsections, if the
2591	2591	22 exercise of eminent domain authority is to acquire property
2592	2592	23 for private ownership or control, or both, then the condemning
2593	2593	24 authority must prove by clear and convincing evidence that the
2594	2594	25 acquisition of the property for private ownership or control
2595	2595	26 is (i) primarily for the benefit, use, or enjoyment of the
2596	2596
2597	2597
2598	2598
2599	2599
2600	2600
2601	2601	HB5021 - 72 - LRB103 36729 LNS 66839 b
2602	2602
2603	2603
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2605	2605	HB5021 - 73 - LRB103 36729 LNS 66839 b
2606	2606	1 public and (ii) necessary for a public purpose.
2607	2607	2 An acquisition of property primarily for the purpose of
2608	2608	3 the elimination of blight is rebuttably presumed to be for a
2609	2609	4 public purpose and primarily for the benefit, use, or
2610	2610	5 enjoyment of the public under this subsection.
2611	2611	6 Any challenge to the existence of blighting factors
2612	2612	7 alleged in a complaint to condemn under this subsection shall
2613	2613	8 be raised within 6 months of the filing date of the complaint
2614	2614	9 to condemn, and if not raised within that time the right to
2615	2615	10 challenge the existence of those blighting factors shall be
2616	2616	11 deemed waived.
2617	2617	12 Evidence that the Illinois Commerce Commission has granted
2618	2618	13 a certificate or otherwise made a finding of public
2619	2619	14 convenience and necessity for an acquisition of property (or
2620	2620	15 any right or interest in property) for private ownership or
2621	2621	16 control (including, without limitation, an acquisition for
2622	2622	17 which the use of eminent domain is authorized under the Public
2623	2623	18 Utilities Act, the Telephone Company Act, or the Electric
2624	2624	19 Supplier Act) to be used for utility purposes creates a
2625	2625	20 rebuttable presumption that such acquisition of that property
2626	2626	21 (or right or interest in property) is (i) primarily for the
2627	2627	22 benefit, use, or enjoyment of the public and (ii) necessary
2628	2628	23 for a public purpose.
2629	2629	24 In the case of an acquisition of property (or any right or
2630	2630	25 interest in property) for private ownership or control to be
2631	2631	26 used for utility, pipeline, or railroad purposes for which no
2632	2632
2633	2633
2634	2634
2635	2635
2636	2636
2637	2637	HB5021 - 73 - LRB103 36729 LNS 66839 b
2638	2638
2639	2639
2640	2640	HB5021- 74 -LRB103 36729 LNS 66839 b HB5021 - 74 - LRB103 36729 LNS 66839 b
2641	2641	HB5021 - 74 - LRB103 36729 LNS 66839 b
2642	2642	1 certificate or finding of public convenience and necessity by
2643	2643	2 the Illinois Commerce Commission is required, evidence that
2644	2644	3 the acquisition is one for which the use of eminent domain is
2645	2645	4 authorized under one of the following laws creates a
2646	2646	5 rebuttable presumption that the acquisition of that property
2647	2647	6 (or right or interest in property) is (i) primarily for the
2648	2648	7 benefit, use, or enjoyment of the public and (ii) necessary
2649	2649	8 for a public purpose:
2650	2650	9 (1) the Public Utilities Act,
2651	2651	10 (2) the Telephone Company Act,
2652	2652	11 (3) the Electric Supplier Act,
2653	2653	12 (4) the Railroad Terminal Authority Act,
2654	2654	13 (5) the Grand Avenue Railroad Relocation Authority
2655	2655	14 Act,
2656	2656	15 (6) the West Cook Railroad Relocation and Development
2657	2657	16 Authority Act,
2658	2658	17 (7) Section 4-505 of the Illinois Highway Code,
2659	2659	18 (8) Section 17 or 18 of the Railroad Incorporation
2660	2660	19 Act,
2661	2661	20 (9) Section 18c-7501 of the Illinois Vehicle Code.
2662	2662	21 (d) If the exercise of eminent domain authority is to
2663	2663	22 acquire property for private ownership or control and if the
2664	2664	23 primary basis for the acquisition is the elimination of blight
2665	2665	24 and the condemning authority elects to proceed under this
2666	2666	25 subsection, then the condemning authority must: (i) prove by a
2667	2667	26 preponderance of the evidence that acquisition of the property
2668	2668
2669	2669
2670	2670
2671	2671
2672	2672
2673	2673	HB5021 - 74 - LRB103 36729 LNS 66839 b
2674	2674
2675	2675
2676	2676	HB5021- 75 -LRB103 36729 LNS 66839 b HB5021 - 75 - LRB103 36729 LNS 66839 b
2677	2677	HB5021 - 75 - LRB103 36729 LNS 66839 b
2678	2678	1 for private ownership or control is necessary for a public
2679	2679	2 purpose; (ii) prove by a preponderance of the evidence that
2680	2680	3 the property to be acquired is located in an area that is
2681	2681	4 currently designated as a blighted area or conservation area
2682	2682	5 under an applicable statute; (iii) if the existence of blight
2683	2683	6 or blighting factors is challenged in an appropriate motion
2684	2684	7 filed within 6 months after the date of filing of the complaint
2685	2685	8 to condemn, prove by a preponderance of the evidence that the
2686	2686	9 required blighting factors existed in the area so designated
2687	2687	10 (but not necessarily in the particular property to be
2688	2688	11 acquired) at the time of the designation under item (ii) or at
2689	2689	12 any time thereafter; and (iv) prove by a preponderance of the
2690	2690	13 evidence at least one of the following:
2691	2691	14 (A) that it has entered into an express written
2692	2692	15 agreement in which a private person or entity agrees to
2693	2693	16 undertake a development project within the blighted area
2694	2694	17 that specifically details the reasons for which the
2695	2695	18 property or rights in that property are necessary for the
2696	2696	19 development project;
2697	2697	20 (B) that the exercise of eminent domain power and the
2698	2698	21 proposed use of the property by the condemning authority
2699	2699	22 are consistent with a regional plan that has been adopted
2700	2700	23 within the past 5 years in accordance with Section 5-14001
2701	2701	24 of the Counties Code or Section 11-12-6 of the Illinois
2702	2702	25 Municipal Code or with a local land resource management
2703	2703	26 plan adopted under Section 4 of the Local Land Resource
2704	2704
2705	2705
2706	2706
2707	2707
2708	2708
2709	2709	HB5021 - 75 - LRB103 36729 LNS 66839 b
2710	2710
2711	2711
2712	2712	HB5021- 76 -LRB103 36729 LNS 66839 b HB5021 - 76 - LRB103 36729 LNS 66839 b
2713	2713	HB5021 - 76 - LRB103 36729 LNS 66839 b
2714	2714	1 Management Planning Act; or
2715	2715	2 (C) that (1) the acquired property will be used in the
2716	2716	3 development of a project that is consistent with the land
2717	2717	4 uses set forth in a comprehensive redevelopment plan
2718	2718	5 prepared in accordance with the applicable statute
2719	2719	6 authorizing the condemning authority to exercise the power
2720	2720	7 of eminent domain and is consistent with the goals and
2721	2721	8 purposes of that comprehensive redevelopment plan, and (2)
2722	2722	9 an enforceable written agreement, deed restriction, or
2723	2723	10 similar encumbrance has been or will be executed and
2724	2724	11 recorded against the acquired property to assure that the
2725	2725	12 project and the use of the property remain consistent with
2726	2726	13 those land uses, goals, and purposes for a period of at
2727	2727	14 least 40 years, which execution and recording shall be
2728	2728	15 included as a requirement in any final order entered in
2729	2729	16 the condemnation proceeding.
2730	2730	17 The existence of an ordinance, resolution, or other
2731	2731	18 official act designating an area as blighted is not prima
2732	2732	19 facie evidence of the existence of blight. A finding by the
2733	2733	20 court in a condemnation proceeding that a property or area has
2734	2734	21 not been proven to be blighted does not apply to any other case
2735	2735	22 or undermine the designation of a blighted area or
2736	2736	23 conservation area or the determination of the existence of
2737	2737	24 blight for any other purpose or under any other statute,
2738	2738	25 including without limitation under the Tax Increment
2739	2739	26 Allocation Redevelopment Act (Article 11, Division 74.4 of the
2740	2740
2741	2741
2742	2742
2743	2743
2744	2744
2745	2745	HB5021 - 76 - LRB103 36729 LNS 66839 b
2746	2746
2747	2747
2748	2748	HB5021- 77 -LRB103 36729 LNS 66839 b HB5021 - 77 - LRB103 36729 LNS 66839 b
2749	2749	HB5021 - 77 - LRB103 36729 LNS 66839 b
2750	2750	1 Illinois Municipal Code).
2751	2751	2 Any challenge to the existence of blighting factors
2752	2752	3 alleged in a complaint to condemn under this subsection shall
2753	2753	4 be raised within 6 months of the filing date of the complaint
2754	2754	5 to condemn, and if not raised within that time the right to
2755	2755	6 challenge the existence of those blighting factors shall be
2756	2756	7 deemed waived.
2757	2757	8 (e) If the exercise of eminent domain authority is to
2758	2758	9 acquire property for private ownership or control and if the
2759	2759	10 primary purpose of the acquisition is one of the purposes
2760	2760	11 specified in item (iii) of this subsection and the condemning
2761	2761	12 authority elects to proceed under this subsection, then the
2762	2762	13 condemning authority must prove by a preponderance of the
2763	2763	14 evidence that: (i) the acquisition of the property is
2764	2764	15 necessary for a public purpose; (ii) an enforceable written
2765	2765	16 agreement, deed restriction, or similar encumbrance has been
2766	2766	17 or will be executed and recorded against the acquired property
2767	2767	18 to assure that the project and the use of the property remain
2768	2768	19 consistent with the applicable purpose specified in item (iii)
2769	2769	20 of this subsection for a period of at least 40 years, which
2770	2770	21 execution and recording shall be included as a requirement in
2771	2771	22 any final order entered in the condemnation proceeding; and
2772	2772	23 (iii) the acquired property will be one of the following:
2773	2773	24 (1) included in the project site for a residential
2774	2774	25 project, or a mixed-use project including residential
2775	2775	26 units, where not less than 20% of the residential units in
2776	2776
2777	2777
2778	2778
2779	2779
2780	2780
2781	2781	HB5021 - 77 - LRB103 36729 LNS 66839 b
2782	2782
2783	2783
2784	2784	HB5021- 78 -LRB103 36729 LNS 66839 b HB5021 - 78 - LRB103 36729 LNS 66839 b
2785	2785	HB5021 - 78 - LRB103 36729 LNS 66839 b
2786	2786	1 the project are made available, for at least 15 years, by
2787	2787	2 deed restriction, long-term lease, regulatory agreement,
2788	2788	3 extended use agreement, or a comparable recorded
2789	2789	4 encumbrance, to low-income households and very low-income
2790	2790	5 households, as defined in Section 3 of the Illinois
2791	2791	6 Affordable Housing Act;
2792	2792	7 (2) used primarily for public airport, road, parking,
2793	2793	8 or mass transportation purposes and sold or leased to a
2794	2794	9 private party in a sale-leaseback, lease-leaseback, or
2795	2795	10 similar structured financing;
2796	2796	11 (3) owned or used by a public utility or electric
2797	2797	12 cooperative for utility purposes;
2798	2798	13 (4) owned or used by a railroad for passenger or
2799	2799	14 freight transportation purposes;
2800	2800	15 (5) sold or leased to a private party that operates a
2801	2801	16 water supply, waste water, recycling, waste disposal,
2802	2802	17 waste-to-energy, or similar facility;
2803	2803	18 (6) sold or leased to a not-for-profit corporation
2804	2804	19 whose purposes include the preservation of open space, the
2805	2805	20 operation of park space, and similar public purposes;
2806	2806	21 (7) used as a library, museum, or related facility, or
2807	2807	22 as infrastructure related to such a facility;
2808	2808	23 (8) used by a private party for the operation of a
2809	2809	24 charter school open to the general public; or
2810	2810	25 (9) a historic resource, as defined in Section 3 of
2811	2811	26 the Illinois State Agency Historic Resources Preservation
2812	2812
2813	2813
2814	2814
2815	2815
2816	2816
2817	2817	HB5021 - 78 - LRB103 36729 LNS 66839 b
2818	2818
2819	2819
2820	2820	HB5021- 79 -LRB103 36729 LNS 66839 b HB5021 - 79 - LRB103 36729 LNS 66839 b
2821	2821	HB5021 - 79 - LRB103 36729 LNS 66839 b
2822	2822	1 Act, a landmark designated as such under a local
2823	2823	2 ordinance, or a contributing structure within a local
2824	2824	3 landmark district listed on the National Register of
2825	2825	4 Historic Places, that is being acquired for purposes of
2826	2826	5 preservation or rehabilitation.
2827	2827	6 (f) If the exercise of eminent domain authority is to
2828	2828	7 acquire property for public ownership and private control and
2829	2829	8 if the primary purpose of the acquisition is one of the
2830	2830	9 purposes specified in item (iii) of this subsection and the
2831	2831	10 condemning authority elects to proceed under this subsection,
2832	2832	11 then the condemning authority must prove by a preponderance of
2833	2833	12 the evidence that: (i) the acquisition of the property is
2834	2834	13 necessary for a public purpose; (ii) the acquired property
2835	2835	14 will be owned by the condemning authority or another
2836	2836	15 governmental entity; and (iii) the acquired property will be
2837	2837	16 controlled by a private party that operates a business or
2838	2838	17 facility related to the condemning authority's operation of a
2839	2839	18 university, medical district, hospital, exposition or
2840	2840	19 convention center, mass transportation facility, or airport,
2841	2841	20 including, but not limited to, a medical clinic, research and
2842	2842	21 development center, food or commercial concession facility,
2843	2843	22 social service facility, maintenance or storage facility,
2844	2844	23 cargo facility, rental car facility, bus facility, taxi
2845	2845	24 facility, flight kitchen, fixed based operation, parking
2846	2846	25 facility, refueling facility, water supply facility, and
2847	2847	26 railroad tracks and stations.
2848	2848
2849	2849
2850	2850
2851	2851
2852	2852
2853	2853	HB5021 - 79 - LRB103 36729 LNS 66839 b
2854	2854
2855	2855
2856	2856	HB5021- 80 -LRB103 36729 LNS 66839 b HB5021 - 80 - LRB103 36729 LNS 66839 b
2857	2857	HB5021 - 80 - LRB103 36729 LNS 66839 b
2858	2858	1 (f-5) For all acquisitions governed by subsection (c)
2859	2859	2 where the property, or any right or interest in property, is to
2860	2860	3 be used for utility purposes, and where the condemning
2861	2861	4 authority is an entity required to submit an integrated
2862	2862	5 resource plan under the Municipal and Cooperative Electric
2863	2863	6 Utility Planning and Transparency Act, the rebuttable
2864	2864	7 presumption described in subsection (c) shall only apply if
2865	2865	8 the most recent integrated resource plan filed by the
2866	2866	9 condemning authority identified the facility or articulated a
2867	2867	10 need for a facility of similar capacity and type to the
2868	2868	11 facility for which the property or right or interest is
2869	2869	12 sought.
2870	2870	13 (g) This Article is a limitation on the exercise of the
2871	2871	14 power of eminent domain, but is not an independent grant of
2872	2872	15 authority to exercise the power of eminent domain.
2873	2873	16 (Source: P.A. 94-1055, eff. 1-1-07.)
2874	2874	17 Section 99. Effective date. This Act takes effect upon
2875	2875	18 becoming law.
2876	2876	HB5021- 81 -LRB103 36729 LNS 66839 b 1 INDEX 2 Statutes amended in order of appearance HB5021- 81 -LRB103 36729 LNS 66839 b HB5021 - 81 - LRB103 36729 LNS 66839 b 1 INDEX 2 Statutes amended in order of appearance
2877	2877	HB5021- 81 -LRB103 36729 LNS 66839 b HB5021 - 81 - LRB103 36729 LNS 66839 b
2878	2878	HB5021 - 81 - LRB103 36729 LNS 66839 b
2879	2879	1 INDEX
2880	2880	2 Statutes amended in order of appearance
2881	2881
2882	2882
2883	2883
2884	2884
2885	2885
2886	2886	HB5021 - 80 - LRB103 36729 LNS 66839 b
2887	2887
2888	2888
2889	2889
2890	2890	HB5021- 81 -LRB103 36729 LNS 66839 b HB5021 - 81 - LRB103 36729 LNS 66839 b
2891	2891	HB5021 - 81 - LRB103 36729 LNS 66839 b
2892	2892	1 INDEX
2893	2893	2 Statutes amended in order of appearance
2894	2894
2895	2895
2896	2896
2897	2897
2898	2898
2899	2899	HB5021 - 81 - LRB103 36729 LNS 66839 b