100TH GENERAL ASSEMBLY
State of Illinois
2017 and 2018
HB5134

 

Introduced , by Rep. Linda Chapa LaVia

 

SYNOPSIS AS INTRODUCED:
 
20 ILCS 3855/1-20
20 ILCS 3855/1-75
220 ILCS 5/16-111.5
220 ILCS 5/16-115A

    Creates the Downstate Illinois Competitive Generation Procurement and Reliability Security Act of 2018 with legislative findings. Provides for the establishment and implementation of an Illinois-specific process for securing electric generation resource adequacy and stable pricing for electric capacity within Midcontinent Independent System Operator, Inc., (MISO) Zone 4. Amends the Illinois Power Agency Act. Authorizes the Illinois Power Agency to develop capacity procurement plans and conduct competitive procurement processes for the procurement of capacity needed to meet the capacity requirements of the retail customers of electric utilities that serve less than 3,000,000 retail customers, but more than 500,000 retail customers in this State. Requires the Agency's Planning and Procurement Bureau to develop plans and processes and conduct competitive procurement processes for the procurement of capacity needed to meet the capacity requirements of the retail customers of electric utilities that serve less than 3,000,000 retail customers, but more than 500,000 retail customers in this State. Modifies the calculation of the projected capacity price for delivering energy under the Act. Amends the Public Utilities Act to make changes regarding capacity procurement and delivery of energy by the Illinois Power Agency and the Illinois Commerce Commission. Makes conforming changes. Defines terms. Effective immediately.


LRB100 20041 SMS 35323 b

 

 

A BILL FOR

 

HB5134LRB100 20041 SMS 35323 b

1    AN ACT concerning regulation.
 
2    Be it enacted by the People of the State of Illinois,
3represented in the General Assembly:
 
4    Section 1. Short title. This Act may be referred to as the
5Downstate Illinois Competitive Generation Procurement and
6Reliability Security Act of 2018.
 
7    Section 5. Legislative findings. The General Assembly
8finds and declares:
9    (1) The overall objectives of regulation of the electric
10utility industry in this State, as expressed by the General
11Assembly in the Illinois Power Agency Act and the Public
12Utilities Act, include the provision of adequate, efficient,
13reliable, environmentally safe, and least-cost utility
14services at prices which accurately reflect the long-term cost
15of such services and which are equitable to all citizens.
16    (2) Through previous enactments beginning in 1997, the
17General Assembly has promoted the use of market-based
18solutions, in combination with adequate regulatory oversight,
19to achieve the objectives of adequate, efficient, reliable,
20environmentally safe and least-cost utility services at prices
21which accurately reflect the long-term cost of such services
22and which are equitable to all citizens.
23    (3) To a significant extent, electricity, when generated,

 

 

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1cannot be stored for future use. Rather, for the most part,
2electricity must be generated instantaneously at the time and
3in the amount that it is demanded by consumers. This requires
4that there be sufficient generating capacity available and
5ready to produce electricity to meet the demands of consumers
6within each load zone in this State, 24 hours per day, 7 days
7per week, on every day of the year. Reliable electric service
8at all times is essential to the functioning of a modern
9economy and of society in general. The health, welfare, and
10prosperity of Illinois citizens, including the attractiveness
11of the State of Illinois to business and industry, requires the
12availability of sufficient electric generating capacity to
13meet the demands of consumers and businesses in this State at
14all times.
15    (4) Consistent with the overall objectives of the
16regulation of the electric utility industry in this State,
17regulation should ensure that sufficient generating capacity
18resources are available on a long-term basis to enable the
19electric utility grid to meet the demands of Illinois
20electricity consumers at all times.
21    (5) The Midcontinent Independent System Operator, Inc., or
22MISO, has been established under federal authority as the
23operator of the electric transmission grid serving
24substantially all of the portion of the State of Illinois
25located south of, and some portions located north of,
26Interstate Highway 80, which area is sometimes referred to as

 

 

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1MISO Zone 4. Overall, MISO's geographic footprint and
2responsibilities as operator of the electric transmission grid
3covers numerous states and multiple load zones. As part of its
4responsibilities, MISO imposes requirements on load-serving
5entities serving electricity consumers in each of MISO's load
6zones for the purpose of ensuring that the load-serving
7entities have access to sufficient electrical generating
8capacity to meet the demands of their customers at all times.
9MISO conducts competitive auctions for the procurement of
10capacity for each of MISO's load zones, which result in the
11establishment of indicative prices for capacity in each load
12zone.
13    (6) All but one of the other MISO load zones in other
14states are unlike Illinois in that electric service in those
15states is provided by vertically integrated electric utilities
16that are subject to traditional cost-based regulation by a
17state utility commission, and there is not a competitive retail
18electricity market in which consumers are allowed to choose
19their electricity suppliers. The processes used by MISO to
20procure and price electric generating capacity in load zones
21located in these other states are not suitable for Illinois,
22which has a competitive retail electricity market and in which
23the major electric utilities no longer own electric generating
24facilities, but obtain electric capacity to meet their
25requirements through competitive wholesale electricity
26markets.

 

 

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1    (7) Prices for electric generating capacity resulting from
2MISO's capacity auctions for Zone 4 have not been stable, but
3have fluctuated significantly in recent years, from a high of
4$150 per megawatt-day in 2015 to a low of $1.50 per
5megawatt-day in 2017. Electric capacity prices that fluctuate
6dramatically, by a factor of 100 to one nearly year to year,
7result in retail electricity prices that impose uncertainty,
8disruption, and potential hardships on consumers and
9businesses in Illinois.
10    (8) Further, the prices for electric generating capacity in
11MISO Zone 4 resulting from several of MISO's recent capacity
12auctions have not been sufficient to incentivize the
13development of new electric generating capacity resources that
14will be committed to serve the demands of electricity consumers
15in Zone 4 over the long run, and in fact, have not been
16sufficient to enable some electric generating facilities
17located within Zone 4 to remain in operation. Electric
18generating facilities are long-lived facilities requiring
19substantial capital investments. Long-term pricing stability,
20at levels sufficient to support the substantial capital
21investment, is necessary to encourage the development of new
22electric generating facilities and to enable existing electric
23generating facilities to remain in operation.
24    (9) Since 2015, electric generating facilities located in
25Illinois within Zone 4 with generating capacity, in the
26aggregate, of more than 1,100 megawatts have been permanently

 

 

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1retired so that this capacity is no longer available to serve
2the demands of Illinois electricity consumers. In this same
3period, additional electric generating facilities with
4capacity of 600 megawatts have been placed into "mothballed"
5status so that this capacity presently is not available to
6serve the needs of Illinois electricity consumers. It is
7estimated that additional electric generating facilities
8located in Illinois within Zone 4 with generating capacity, in
9the aggregate, of at least 3,000 megawatts is currently at risk
10of retirement in light of low prices for electric generating
11capacity prevailing in Zone 4.
12    (10) MISO has advised the Governor of the State of Illinois
13and the leadership of the General Assembly that MISO prefers
14state-based solutions to achieving resource adequacy and
15ensuring that sufficient electric resources continue to be
16available in downstate Illinois to maintain reliable service
17for consumers at times of peak electricity demand, and that
18additional action is needed in downstate Illinois to maintain
19reliability of electric service. MISO has further stated that
20without further action to develop an Illinois-based solution
21for long term adequacy of electric capacity resources in
22downstate Illinois, the outlook for reliable electric service
23in downstate Illinois is unclear and uncertain from year to
24year.
25    (11) Consistent with MISO's recommendations, there is a
26need to establish an Illinois-specific process for procuring

 

 

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1electric capacity to meet the needs of electricity consumers in
2MISO Zone 4 that are served by Illinois electric utilities and
3alternative retail electric suppliers. Such a process should
4(i) be consistent to the extent feasible with existing
5processes of MISO; (ii) rely to the extent feasible on
6competitive market-based approaches; (iii) provide for the
7procurement of electric generating capacity, to the maximum
8extent feasible, on a long-term forward basis of at least 3
9years, rather than on a shorter-term basis, in order to provide
10incentives for the development of new electric generating
11facilities and the retention of existing electric generating
12facilities that are and will be committed to serving the
13electricity requirements of electricity consumers within MISO
14Zone 4 in Illinois; (iv) be open to all forms of electric
15generating capacity that meet MISO's operational and
16availability requirements; and (v) be administered and
17overseen by the Illinois Power Agency and the Illinois Commerce
18Commission.
19    (12) The General Assembly therefore finds and declares that
20it is necessary for the health, welfare, and prosperity of the
21citizens and businesses of Illinois located within the portion
22of Illinois encompassed by MISO Zone 4, to establish and
23implement an Illinois-specific process for securing electric
24generation resource adequacy and stable pricing for electric
25capacity within MISO Zone 4, through the adoption of this Act.
 

 

 

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1    Section 10. The Illinois Power Agency Act is amended by
2changing Sections 1-20 and 1-75 as follows:
 
3    (20 ILCS 3855/1-20)
4    Sec. 1-20. General powers of the Agency.
5    (a) The Agency is authorized to do each of the following:
6        (1) Develop electricity procurement plans to ensure
7    adequate, reliable, affordable, efficient, and
8    environmentally sustainable electric service at the lowest
9    total cost over time, taking into account any benefits of
10    price stability, for electric utilities that on December
11    31, 2005 provided electric service to at least 100,000
12    customers in Illinois and for small multi-jurisdictional
13    electric utilities that (A) on December 31, 2005 served
14    less than 100,000 customers in Illinois and (B) request a
15    procurement plan for their Illinois jurisdictional load.
16    Except as provided in paragraph (1.5) of this subsection
17    (a), the electricity procurement plans shall be updated on
18    an annual basis and shall include electricity generated
19    from renewable resources sufficient to achieve the
20    standards specified in this Act. Beginning with the
21    delivery year commencing June 1, 2017, develop procurement
22    plans to include zero emission credits generated from zero
23    emission facilities sufficient to achieve the standards
24    specified in this Act.
25        (1.5) Develop a long-term renewable resources

 

 

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1    procurement plan in accordance with subsection (c) of
2    Section 1-75 of this Act for renewable energy credits in
3    amounts sufficient to achieve the standards specified in
4    this Act for delivery years commencing June 1, 2017 and for
5    the programs and renewable energy credits specified in
6    Section 1-56 of this Act. Electricity procurement plans for
7    delivery years commencing after May 31, 2017, shall not
8    include procurement of renewable energy resources.
9        (2) Conduct competitive procurement processes to
10    procure the supply resources identified in the electricity
11    procurement plan, pursuant to Section 16-111.5 of the
12    Public Utilities Act, and, for the delivery year commencing
13    June 1, 2017, conduct procurement processes to procure zero
14    emission credits from zero emission facilities, under
15    subsection (d-5) of Section 1-75 of this Act.
16        (2.5) Beginning with the procurement for the 2017
17    delivery year, conduct competitive procurement processes
18    and implement programs to procure renewable energy credits
19    identified in the long-term renewable resources
20    procurement plan developed and approved under subsection
21    (c) of Section 1-75 of this Act and Section 16-111.5 of the
22    Public Utilities Act.
23        (2.10) Beginning with the procurement for the delivery
24    year commencing June 1, 2019, develop capacity procurement
25    plans and conduct competitive procurement processes for
26    the procurement of capacity needed to ensure long-term

 

 

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1    resource adequacy at the lowest cost over time, taking into
2    account the benefits of price stability and the need to
3    ensure the reliability, adequacy, and resilience of the
4    bulk power generation and delivery system in the Applicable
5    Local Resource Zone, as defined in Section 1-75 of this
6    Act, to meet the capacity requirements of the retail
7    customers of electric utilities that serve less than
8    3,000,000 retail customers, but more than 500,000 retail
9    customers in this State.
10        (3) Develop electric generation and co-generation
11    facilities that use indigenous coal or renewable
12    resources, or both, financed with bonds issued by the
13    Illinois Finance Authority.
14        (4) Supply electricity from the Agency's facilities at
15    cost to one or more of the following: municipal electric
16    systems, governmental aggregators, or rural electric
17    cooperatives in Illinois.
18    (b) Except as otherwise limited by this Act, the Agency has
19all of the powers necessary or convenient to carry out the
20purposes and provisions of this Act, including without
21limitation, each of the following:
22        (1) To have a corporate seal, and to alter that seal at
23    pleasure, and to use it by causing it or a facsimile to be
24    affixed or impressed or reproduced in any other manner.
25        (2) To use the services of the Illinois Finance
26    Authority necessary to carry out the Agency's purposes.

 

 

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1        (3) To negotiate and enter into loan agreements and
2    other agreements with the Illinois Finance Authority.
3        (4) To obtain and employ personnel and hire consultants
4    that are necessary to fulfill the Agency's purposes, and to
5    make expenditures for that purpose within the
6    appropriations for that purpose.
7        (5) To purchase, receive, take by grant, gift, devise,
8    bequest, or otherwise, lease, or otherwise acquire, own,
9    hold, improve, employ, use, and otherwise deal in and with,
10    real or personal property whether tangible or intangible,
11    or any interest therein, within the State.
12        (6) To acquire real or personal property, whether
13    tangible or intangible, including without limitation
14    property rights, interests in property, franchises,
15    obligations, contracts, and debt and equity securities,
16    and to do so by the exercise of the power of eminent domain
17    in accordance with Section 1-21; except that any real
18    property acquired by the exercise of the power of eminent
19    domain must be located within the State.
20        (7) To sell, convey, lease, exchange, transfer,
21    abandon, or otherwise dispose of, or mortgage, pledge, or
22    create a security interest in, any of its assets,
23    properties, or any interest therein, wherever situated.
24        (8) To purchase, take, receive, subscribe for, or
25    otherwise acquire, hold, make a tender offer for, vote,
26    employ, sell, lend, lease, exchange, transfer, or

 

 

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1    otherwise dispose of, mortgage, pledge, or grant a security
2    interest in, use, and otherwise deal in and with, bonds and
3    other obligations, shares, or other securities (or
4    interests therein) issued by others, whether engaged in a
5    similar or different business or activity.
6        (9) To make and execute agreements, contracts, and
7    other instruments necessary or convenient in the exercise
8    of the powers and functions of the Agency under this Act,
9    including contracts with any person, including personal
10    service contracts, or with any local government, State
11    agency, or other entity; and all State agencies and all
12    local governments are authorized to enter into and do all
13    things necessary to perform any such agreement, contract,
14    or other instrument with the Agency. No such agreement,
15    contract, or other instrument shall exceed 40 years.
16        (10) To lend money, invest and reinvest its funds in
17    accordance with the Public Funds Investment Act, and take
18    and hold real and personal property as security for the
19    payment of funds loaned or invested.
20        (11) To borrow money at such rate or rates of interest
21    as the Agency may determine, issue its notes, bonds, or
22    other obligations to evidence that indebtedness, and
23    secure any of its obligations by mortgage or pledge of its
24    real or personal property, machinery, equipment,
25    structures, fixtures, inventories, revenues, grants, and
26    other funds as provided or any interest therein, wherever

 

 

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1    situated.
2        (12) To enter into agreements with the Illinois Finance
3    Authority to issue bonds whether or not the income
4    therefrom is exempt from federal taxation.
5        (13) To procure insurance against any loss in
6    connection with its properties or operations in such amount
7    or amounts and from such insurers, including the federal
8    government, as it may deem necessary or desirable, and to
9    pay any premiums therefor.
10        (14) To negotiate and enter into agreements with
11    trustees or receivers appointed by United States
12    bankruptcy courts or federal district courts or in other
13    proceedings involving adjustment of debts and authorize
14    proceedings involving adjustment of debts and authorize
15    legal counsel for the Agency to appear in any such
16    proceedings.
17        (15) To file a petition under Chapter 9 of Title 11 of
18    the United States Bankruptcy Code or take other similar
19    action for the adjustment of its debts.
20        (16) To enter into management agreements for the
21    operation of any of the property or facilities owned by the
22    Agency.
23        (17) To enter into an agreement to transfer and to
24    transfer any land, facilities, fixtures, or equipment of
25    the Agency to one or more municipal electric systems,
26    governmental aggregators, or rural electric agencies or

 

 

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1    cooperatives, for such consideration and upon such terms as
2    the Agency may determine to be in the best interest of the
3    citizens of Illinois.
4        (18) To enter upon any lands and within any building
5    whenever in its judgment it may be necessary for the
6    purpose of making surveys and examinations to accomplish
7    any purpose authorized by this Act.
8        (19) To maintain an office or offices at such place or
9    places in the State as it may determine.
10        (20) To request information, and to make any inquiry,
11    investigation, survey, or study that the Agency may deem
12    necessary to enable it effectively to carry out the
13    provisions of this Act.
14        (21) To accept and expend appropriations.
15        (22) To engage in any activity or operation that is
16    incidental to and in furtherance of efficient operation to
17    accomplish the Agency's purposes, including hiring
18    employees that the Director deems essential for the
19    operations of the Agency.
20        (23) To adopt, revise, amend, and repeal rules with
21    respect to its operations, properties, and facilities as
22    may be necessary or convenient to carry out the purposes of
23    this Act, subject to the provisions of the Illinois
24    Administrative Procedure Act and Sections 1-22 and 1-35 of
25    this Act.
26        (24) To establish and collect charges and fees as

 

 

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1    described in this Act.
2        (25) To conduct competitive gasification feedstock
3    procurement processes to procure the feedstocks for the
4    clean coal SNG brownfield facility in accordance with the
5    requirements of Section 1-78 of this Act.
6        (26) To review, revise, and approve sourcing
7    agreements and mediate and resolve disputes between gas
8    utilities and the clean coal SNG brownfield facility
9    pursuant to subsection (h-1) of Section 9-220 of the Public
10    Utilities Act.
11        (27) To request, review and accept proposals, execute
12    contracts, purchase renewable energy credits and otherwise
13    dedicate funds from the Illinois Power Agency Renewable
14    Energy Resources Fund to create and carry out the
15    objectives of the Illinois Solar for All program in
16    accordance with Section 1-56 of this Act.
17(Source: P.A. 99-906, eff. 6-1-17.)
 
18    (20 ILCS 3855/1-75)
19    Sec. 1-75. Planning and Procurement Bureau. The Planning
20and Procurement Bureau has the following duties and
21responsibilities:
22    (a) The Planning and Procurement Bureau shall each year,
23beginning in 2008, develop procurement plans and conduct
24competitive procurement processes in accordance with the
25requirements of Section 16-111.5 of the Public Utilities Act

 

 

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1for the eligible retail customers of electric utilities that on
2December 31, 2005 provided electric service to at least 100,000
3customers in Illinois. Beginning with the delivery year
4commencing on June 1, 2017, the Planning and Procurement Bureau
5shall develop plans and processes for the procurement of zero
6emission credits from zero emission facilities in accordance
7with the requirements of subsection (d-5) of this Section. The
8Planning and Procurement Bureau shall also develop procurement
9plans and conduct competitive procurement processes in
10accordance with the requirements of Section 16-111.5 of the
11Public Utilities Act for the eligible retail customers of small
12multi-jurisdictional electric utilities that (i) on December
1331, 2005 served less than 100,000 customers in Illinois and
14(ii) request a procurement plan for their Illinois
15jurisdictional load. This Section shall not apply to a small
16multi-jurisdictional utility until such time as a small
17multi-jurisdictional utility requests the Agency to prepare a
18procurement plan for their Illinois jurisdictional load. For
19the purposes of this Section, the term "eligible retail
20customers" has the same definition as found in Section
2116-111.5(a) of the Public Utilities Act.
22    Beginning with the plan or plans to be implemented in the
232017 delivery year, the Agency shall no longer include the
24procurement of renewable energy resources in the annual
25procurement plans required by this subsection (a), except as
26provided in subsection (q) of Section 16-111.5 of the Public

 

 

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1Utilities Act, and shall instead develop a long-term renewable
2resources procurement plan in accordance with subsection (c) of
3this Section and Section 16-111.5 of the Public Utilities Act.
4    Beginning with the procurement for the delivery year
5commencing June 1, 2019, the Planning and Procurement Bureau
6shall for each year develop plans and processes for and conduct
7competitive procurement processes in accordance with
8subsection (b-5) of Section 16-111.5 of the Public Utilities
9Act and paragraph (2.10) of subsection (a) of Section 1-20 of
10this Act, the results of which shall be subject to approval of
11the Commission in accordance with subsection (f) of Section
1216-111.5 of the Public Utilities Act, for the procurement of
13capacity needed to meet the capacity requirements of the retail
14customers of electric utilities that serve less than 3,000,000
15retail customers, but more than 500,000 retail customers in
16this State and are located in the Applicable Local Resource
17Zone of the Midcontinent Independent System Operator, Inc., or
18its successor. For purposes of this Section, "Local Resource
19Zone" shall have the meaning set forth in the open access
20transmission and energy markets tariff of the Midcontinent
21Independent System Operator, Inc., or its successor, as such
22tariff may be updated from time to time, and "Applicable Local
23Resource Zone" means the Local Resource Zone or Zones within
24the Midcontinent Independent System Operator, that incorporate
25all retail customers of electric utilities that serve less than
263,000,000 retail customers, but more than 500,000 retail

 

 

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1customers in this State.
2        (1) The Agency shall each year, beginning in 2008, as
3    needed, issue a request for qualifications for experts or
4    expert consulting firms to develop the procurement plans in
5    accordance with Section 16-111.5 of the Public Utilities
6    Act. In order to qualify an expert or expert consulting
7    firm must have:
8            (A) direct previous experience assembling
9        large-scale power supply plans or portfolios for
10        end-use customers;
11            (B) an advanced degree in economics, mathematics,
12        engineering, risk management, or a related area of
13        study;
14            (C) 10 years of experience in the electricity
15        sector, including managing supply risk;
16            (D) expertise in wholesale electricity market
17        rules, including those established by the Federal
18        Energy Regulatory Commission and regional transmission
19        organizations;
20            (E) expertise in credit protocols and familiarity
21        with contract protocols;
22            (F) adequate resources to perform and fulfill the
23        required functions and responsibilities; and
24            (G) the absence of a conflict of interest and
25        inappropriate bias for or against potential bidders or
26        the affected electric utilities.

 

 

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1        (2) The Agency shall each year, as needed, issue a
2    request for qualifications for a procurement administrator
3    to conduct the competitive procurement processes in
4    accordance with Section 16-111.5 of the Public Utilities
5    Act. In order to qualify an expert or expert consulting
6    firm must have:
7            (A) direct previous experience administering a
8        large-scale competitive procurement process;
9            (B) an advanced degree in economics, mathematics,
10        engineering, or a related area of study;
11            (C) 10 years of experience in the electricity
12        sector, including risk management experience;
13            (D) expertise in wholesale electricity market
14        rules, including those established by the Federal
15        Energy Regulatory Commission and regional transmission
16        organizations;
17            (E) expertise in credit and contract protocols;
18            (F) adequate resources to perform and fulfill the
19        required functions and responsibilities; and
20            (G) the absence of a conflict of interest and
21        inappropriate bias for or against potential bidders or
22        the affected electric utilities.
23        (3) The Agency shall provide affected utilities and
24    other interested parties with the lists of qualified
25    experts or expert consulting firms identified through the
26    request for qualifications processes that are under

 

 

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1    consideration to develop the procurement plans and to serve
2    as the procurement administrator. The Agency shall also
3    provide each qualified expert's or expert consulting
4    firm's response to the request for qualifications. All
5    information provided under this subparagraph shall also be
6    provided to the Commission. The Agency may provide by rule
7    for fees associated with supplying the information to
8    utilities and other interested parties. These parties
9    shall, within 5 business days, notify the Agency in writing
10    if they object to any experts or expert consulting firms on
11    the lists. Objections shall be based on:
12            (A) failure to satisfy qualification criteria;
13            (B) identification of a conflict of interest; or
14            (C) evidence of inappropriate bias for or against
15        potential bidders or the affected utilities.
16        The Agency shall remove experts or expert consulting
17    firms from the lists within 10 days if there is a
18    reasonable basis for an objection and provide the updated
19    lists to the affected utilities and other interested
20    parties. If the Agency fails to remove an expert or expert
21    consulting firm from a list, an objecting party may seek
22    review by the Commission within 5 days thereafter by filing
23    a petition, and the Commission shall render a ruling on the
24    petition within 10 days. There is no right of appeal of the
25    Commission's ruling.
26        (4) The Agency shall issue requests for proposals to

 

 

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1    the qualified experts or expert consulting firms to develop
2    a procurement plan for the affected utilities and to serve
3    as procurement administrator.
4        (5) The Agency shall select an expert or expert
5    consulting firm to develop procurement plans based on the
6    proposals submitted and shall award contracts of up to 5
7    years to those selected.
8        (6) The Agency shall select an expert or expert
9    consulting firm, with approval of the Commission, to serve
10    as procurement administrator based on the proposals
11    submitted. If the Commission rejects, within 5 days, the
12    Agency's selection, the Agency shall submit another
13    recommendation within 3 days based on the proposals
14    submitted. The Agency shall award a 5-year contract to the
15    expert or expert consulting firm so selected with
16    Commission approval.
17    (b) The experts or expert consulting firms retained by the
18Agency shall, as appropriate, prepare procurement plans, and
19conduct a competitive procurement process as prescribed in
20Section 16-111.5 of the Public Utilities Act, to ensure
21adequate, reliable, affordable, efficient, and environmentally
22sustainable electric service at the lowest total cost over
23time, taking into account any benefits of price stability, for
24eligible retail customers of electric utilities that on
25December 31, 2005 provided electric service to at least 100,000
26customers in the State of Illinois, and for eligible Illinois

 

 

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1retail customers of small multi-jurisdictional electric
2utilities that (i) on December 31, 2005 served less than
3100,000 customers in Illinois and (ii) request a procurement
4plan for their Illinois jurisdictional load.
5    (c) Renewable portfolio standard.
6        (1)(A) The Agency shall develop a long-term renewable
7    resources procurement plan that shall include procurement
8    programs and competitive procurement events necessary to
9    meet the goals set forth in this subsection (c). The
10    initial long-term renewable resources procurement plan
11    shall be released for comment no later than 160 days after
12    June 1, 2017 (the effective date of Public Act 99-906) this
13    amendatory Act of the 99th General Assembly. The Agency
14    shall review, and may revise on an expedited basis, the
15    long-term renewable resources procurement plan at least
16    every 2 years, which shall be conducted in conjunction with
17    the procurement plan under Section 16-111.5 of the Public
18    Utilities Act to the extent practicable to minimize
19    administrative expense. The long-term renewable resources
20    procurement plans shall be subject to review and approval
21    by the Commission under Section 16-111.5 of the Public
22    Utilities Act.
23        (B) Subject to subparagraph (F) of this paragraph (1),
24    the long-term renewable resources procurement plan shall
25    include the goals for procurement of renewable energy
26    credits to meet at least the following overall percentages:

 

 

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1    13% by the 2017 delivery year; increasing by at least 1.5%
2    each delivery year thereafter to at least 25% by the 2025
3    delivery year; and continuing at no less than 25% for each
4    delivery year thereafter. In the event of a conflict
5    between these goals and the new wind and new photovoltaic
6    procurement requirements described in items (i) through
7    (iii) of subparagraph (C) of this paragraph (1), the
8    long-term plan shall prioritize compliance with the new
9    wind and new photovoltaic procurement requirements
10    described in items (i) through (iii) of subparagraph (C) of
11    this paragraph (1) over the annual percentage targets
12    described in this subparagraph (B).
13        For the delivery year beginning June 1, 2017, the
14    procurement plan shall include cost-effective renewable
15    energy resources equal to at least 13% of each utility's
16    load for eligible retail customers and 13% of the
17    applicable portion of each utility's load for retail
18    customers who are not eligible retail customers, which
19    applicable portion shall equal 50% of the utility's load
20    for retail customers who are not eligible retail customers
21    on February 28, 2017.
22        For the delivery year beginning June 1, 2018, the
23    procurement plan shall include cost-effective renewable
24    energy resources equal to at least 14.5% of each utility's
25    load for eligible retail customers and 14.5% of the
26    applicable portion of each utility's load for retail

 

 

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1    customers who are not eligible retail customers, which
2    applicable portion shall equal 75% of the utility's load
3    for retail customers who are not eligible retail customers
4    on February 28, 2017.
5        For the delivery year beginning June 1, 2019, and for
6    each year thereafter, the procurement plans shall include
7    cost-effective renewable energy resources equal to a
8    minimum percentage of each utility's load for all retail
9    customers as follows: 16% by June 1, 2019; increasing by
10    1.5% each year thereafter to 25% by June 1, 2025; and 25%
11    by June 1, 2026 and each year thereafter.
12        For each delivery year, the Agency shall first
13    recognize each utility's obligations for that delivery
14    year under existing contracts. Any renewable energy
15    credits under existing contracts, including renewable
16    energy credits as part of renewable energy resources, shall
17    be used to meet the goals set forth in this subsection (c)
18    for the delivery year.
19        (C) Of the renewable energy credits procured under this
20    subsection (c), at least 75% shall come from wind and
21    photovoltaic projects. The long-term renewable resources
22    procurement plan described in subparagraph (A) of this
23    paragraph (1) shall include the procurement of renewable
24    energy credits in amounts equal to at least the following:
25            (i) By the end of the 2020 delivery year:
26                At least 2,000,000 renewable energy credits

 

 

HB5134- 24 -LRB100 20041 SMS 35323 b

1            for each delivery year shall come from new wind
2            projects; and
3                At least 2,000,000 renewable energy credits
4            for each delivery year shall come from new
5            photovoltaic projects; of that amount, to the
6            extent possible, the Agency shall procure: at
7            least 50% from solar photovoltaic projects using
8            the program outlined in subparagraph (K) of this
9            paragraph (1) from distributed renewable energy
10            generation devices or community renewable
11            generation projects; at least 40% from
12            utility-scale solar projects; at least 2% from
13            brownfield site photovoltaic projects that are not
14            community renewable generation projects; and the
15            remainder shall be determined through the
16            long-term planning process described in
17            subparagraph (A) of this paragraph (1).
18            (ii) By the end of the 2025 delivery year:
19                At least 3,000,000 renewable energy credits
20            for each delivery year shall come from new wind
21            projects; and
22                At least 3,000,000 renewable energy credits
23            for each delivery year shall come from new
24            photovoltaic projects; of that amount, to the
25            extent possible, the Agency shall procure: at
26            least 50% from solar photovoltaic projects using

 

 

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1            the program outlined in subparagraph (K) of this
2            paragraph (1) from distributed renewable energy
3            devices or community renewable generation
4            projects; at least 40% from utility-scale solar
5            projects; at least 2% from brownfield site
6            photovoltaic projects that are not community
7            renewable generation projects; and the remainder
8            shall be determined through the long-term planning
9            process described in subparagraph (A) of this
10            paragraph (1).
11            (iii) By the end of the 2030 delivery year:
12                At least 4,000,000 renewable energy credits
13            for each delivery year shall come from new wind
14            projects; and
15                At least 4,000,000 renewable energy credits
16            for each delivery year shall come from new
17            photovoltaic projects; of that amount, to the
18            extent possible, the Agency shall procure: at
19            least 50% from solar photovoltaic projects using
20            the program outlined in subparagraph (K) of this
21            paragraph (1) from distributed renewable energy
22            devices or community renewable generation
23            projects; at least 40% from utility-scale solar
24            projects; at least 2% from brownfield site
25            photovoltaic projects that are not community
26            renewable generation projects; and the remainder

 

 

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1            shall be determined through the long-term planning
2            process described in subparagraph (A) of this
3            paragraph (1).
4            For purposes of this Section:
5                "New wind projects" means wind renewable
6            energy facilities that are energized after June 1,
7            2017 for the delivery year commencing June 1, 2017
8            or within 3 years after the date the Commission
9            approves contracts for subsequent delivery years.
10                "New photovoltaic projects" means photovoltaic
11            renewable energy facilities that are energized
12            after June 1, 2017. Photovoltaic projects
13            developed under Section 1-56 of this Act shall not
14            apply towards the new photovoltaic project
15            requirements in this subparagraph (C).
16        (D) Renewable energy credits shall be cost effective.
17    For purposes of this subsection (c), "cost effective" means
18    that the costs of procuring renewable energy resources do
19    not cause the limit stated in subparagraph (E) of this
20    paragraph (1) to be exceeded and, for renewable energy
21    credits procured through a competitive procurement event,
22    do not exceed benchmarks based on market prices for like
23    products in the region. For purposes of this subsection
24    (c), "like products" means contracts for renewable energy
25    credits from the same or substantially similar technology,
26    same or substantially similar vintage (new or existing),

 

 

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1    the same or substantially similar quantity, and the same or
2    substantially similar contract length and structure.
3    Benchmarks shall be developed by the procurement
4    administrator, in consultation with the Commission staff,
5    Agency staff, and the procurement monitor and shall be
6    subject to Commission review and approval. If price
7    benchmarks for like products in the region are not
8    available, the procurement administrator shall establish
9    price benchmarks based on publicly available data on
10    regional technology costs and expected current and future
11    regional energy prices. The benchmarks in this Section
12    shall not be used to curtail or otherwise reduce
13    contractual obligations entered into by or through the
14    Agency prior to June 1, 2017 (the effective date of Public
15    Act 99-906) this amendatory Act of the 99th General
16    Assembly.
17        (E) For purposes of this subsection (c), the required
18    procurement of cost-effective renewable energy resources
19    for a particular year commencing prior to June 1, 2017
20    shall be measured as a percentage of the actual amount of
21    electricity (megawatt-hours) supplied by the electric
22    utility to eligible retail customers in the delivery year
23    ending immediately prior to the procurement, and, for
24    delivery years commencing on and after June 1, 2017, the
25    required procurement of cost-effective renewable energy
26    resources for a particular year shall be measured as a

 

 

HB5134- 28 -LRB100 20041 SMS 35323 b

1    percentage of the actual amount of electricity
2    (megawatt-hours) delivered by the electric utility in the
3    delivery year ending immediately prior to the procurement,
4    to all retail customers in its service territory. For
5    purposes of this subsection (c), the amount paid per
6    kilowatthour means the total amount paid for electric
7    service expressed on a per kilowatthour basis. For purposes
8    of this subsection (c), the total amount paid for electric
9    service includes without limitation amounts paid for
10    supply, transmission, distribution, surcharges, and add-on
11    taxes.
12        Notwithstanding the requirements of this subsection
13    (c), the total of renewable energy resources procured under
14    the procurement plan for any single year shall be subject
15    to the limitations of this subparagraph (E). Such
16    procurement shall be reduced for all retail customers based
17    on the amount necessary to limit the annual estimated
18    average net increase due to the costs of these resources
19    included in the amounts paid by eligible retail customers
20    in connection with electric service to no more than the
21    greater of 2.015% of the amount paid per kilowatthour by
22    those customers during the year ending May 31, 2007 or the
23    incremental amount per kilowatthour paid for these
24    resources in 2011. To arrive at a maximum dollar amount of
25    renewable energy resources to be procured for the
26    particular delivery year, the resulting per kilowatthour

 

 

HB5134- 29 -LRB100 20041 SMS 35323 b

1    amount shall be applied to the actual amount of
2    kilowatthours of electricity delivered, or applicable
3    portion of such amount as specified in paragraph (1) of
4    this subsection (c), as applicable, by the electric utility
5    in the delivery year immediately prior to the procurement
6    to all retail customers in its service territory. The
7    calculations required by this subparagraph (E) shall be
8    made only once for each delivery year at the time that the
9    renewable energy resources are procured. Once the
10    determination as to the amount of renewable energy
11    resources to procure is made based on the calculations set
12    forth in this subparagraph (E) and the contracts procuring
13    those amounts are executed, no subsequent rate impact
14    determinations shall be made and no adjustments to those
15    contract amounts shall be allowed. All costs incurred under
16    such contracts shall be fully recoverable by the electric
17    utility as provided in this Section.
18        (F) If the limitation on the amount of renewable energy
19    resources procured in subparagraph (E) of this paragraph
20    (1) prevents the Agency from meeting all of the goals in
21    this subsection (c), the Agency's long-term plan shall
22    prioritize compliance with the requirements of this
23    subsection (c) regarding renewable energy credits in the
24    following order:
25            (i) renewable energy credits under existing
26        contractual obligations;

 

 

HB5134- 30 -LRB100 20041 SMS 35323 b

1            (i-5) funding for the Illinois Solar for All
2        Program, as described in subparagraph (O) of this
3        paragraph (1);
4            (ii) renewable energy credits necessary to comply
5        with the new wind and new photovoltaic procurement
6        requirements described in items (i) through (iii) of
7        subparagraph (C) of this paragraph (1); and
8            (iii) renewable energy credits necessary to meet
9        the remaining requirements of this subsection (c).
10        (G) The following provisions shall apply to the
11    Agency's procurement of renewable energy credits under
12    this subsection (c):
13            (i) Notwithstanding whether a long-term renewable
14        resources procurement plan has been approved, the
15        Agency shall conduct an initial forward procurement
16        for renewable energy credits from new utility-scale
17        wind projects within 160 days after June 1, 2017 (the
18        effective date of Public Act 99-906) this amendatory
19        Act of the 99th General Assembly. For the purposes of
20        this initial forward procurement, the Agency shall
21        solicit 15-year contracts for delivery of 1,000,000
22        renewable energy credits delivered annually from new
23        utility-scale wind projects to begin delivery on June
24        1, 2019, if available, but not later than June 1, 2021.
25        Payments to suppliers of renewable energy credits
26        shall commence upon delivery. Renewable energy credits

 

 

HB5134- 31 -LRB100 20041 SMS 35323 b

1        procured under this initial procurement shall be
2        included in the Agency's long-term plan and shall apply
3        to all renewable energy goals in this subsection (c).
4            (ii) Notwithstanding whether a long-term renewable
5        resources procurement plan has been approved, the
6        Agency shall conduct an initial forward procurement
7        for renewable energy credits from new utility-scale
8        solar projects and brownfield site photovoltaic
9        projects within one year after June 1, 2017 (the
10        effective date of Public Act 99-906) this amendatory
11        Act of the 99th General Assembly. For the purposes of
12        this initial forward procurement, the Agency shall
13        solicit 15-year contracts for delivery of 1,000,000
14        renewable energy credits delivered annually from new
15        utility-scale solar projects and brownfield site
16        photovoltaic projects to begin delivery on June 1,
17        2019, if available, but not later than June 1, 2021.
18        The Agency may structure this initial procurement in
19        one or more discrete procurement events. Payments to
20        suppliers of renewable energy credits shall commence
21        upon delivery. Renewable energy credits procured under
22        this initial procurement shall be included in the
23        Agency's long-term plan and shall apply to all
24        renewable energy goals in this subsection (c).
25            (iii) Subsequent forward procurements for
26        utility-scale wind projects shall solicit at least

 

 

HB5134- 32 -LRB100 20041 SMS 35323 b

1        1,000,000 renewable energy credits delivered annually
2        per procurement event and shall be planned, scheduled,
3        and designed such that the cumulative amount of
4        renewable energy credits delivered from all new wind
5        projects in each delivery year shall not exceed the
6        Agency's projection of the cumulative amount of
7        renewable energy credits that will be delivered from
8        all new photovoltaic projects, including utility-scale
9        and distributed photovoltaic devices, in the same
10        delivery year at the time scheduled for wind contract
11        delivery.
12            (iv) If, at any time after the time set for
13        delivery of renewable energy credits pursuant to the
14        initial procurements in items (i) and (ii) of this
15        subparagraph (G), the cumulative amount of renewable
16        energy credits projected to be delivered from all new
17        wind projects in a given delivery year exceeds the
18        cumulative amount of renewable energy credits
19        projected to be delivered from all new photovoltaic
20        projects in that delivery year by 200,000 or more
21        renewable energy credits, then the Agency shall within
22        60 days adjust the procurement programs in the
23        long-term renewable resources procurement plan to
24        ensure that the projected cumulative amount of
25        renewable energy credits to be delivered from all new
26        wind projects does not exceed the projected cumulative

 

 

HB5134- 33 -LRB100 20041 SMS 35323 b

1        amount of renewable energy credits to be delivered from
2        all new photovoltaic projects by 200,000 or more
3        renewable energy credits, provided that nothing in
4        this Section shall preclude the projected cumulative
5        amount of renewable energy credits to be delivered from
6        all new photovoltaic projects from exceeding the
7        projected cumulative amount of renewable energy
8        credits to be delivered from all new wind projects in
9        each delivery year and provided further that nothing in
10        this item (iv) shall require the curtailment of an
11        executed contract. The Agency shall update, on a
12        quarterly basis, its projection of the renewable
13        energy credits to be delivered from all projects in
14        each delivery year. Notwithstanding anything to the
15        contrary, the Agency may adjust the timing of
16        procurement events conducted under this subparagraph
17        (G). The long-term renewable resources procurement
18        plan shall set forth the process by which the
19        adjustments may be made.
20            (v) All procurements under this subparagraph (G)
21        shall comply with the geographic requirements in
22        subparagraph (I) of this paragraph (1) and shall follow
23        the procurement processes and procedures described in
24        this Section and Section 16-111.5 of the Public
25        Utilities Act to the extent practicable, and these
26        processes and procedures may be expedited to

 

 

HB5134- 34 -LRB100 20041 SMS 35323 b

1        accommodate the schedule established by this
2        subparagraph (G).
3        (H) The procurement of renewable energy resources for a
4    given delivery year shall be reduced as described in this
5    subparagraph (H) if an alternative alternate retail
6    electric supplier meets the requirements described in this
7    subparagraph (H).
8            (i) Within 45 days after June 1, 2017 (the
9        effective date of Public Act 99-906) this amendatory
10        Act of the 99th General Assembly, an alternative retail
11        electric supplier or its successor shall submit an
12        informational filing to the Illinois Commerce
13        Commission certifying that, as of December 31, 2015,
14        the alternative retail electric supplier owned one or
15        more electric generating facilities that generates
16        renewable energy resources as defined in Section 1-10
17        of this Act, provided that such facilities are not
18        powered by wind or photovoltaics, and the facilities
19        generate one renewable energy credit for each
20        megawatthour of energy produced from the facility.
21            The informational filing shall identify each
22        facility that was eligible to satisfy the alternative
23        retail electric supplier's obligations under Section
24        16-115D of the Public Utilities Act as described in
25        this item (i).
26            (ii) For a given delivery year, the alternative

 

 

HB5134- 35 -LRB100 20041 SMS 35323 b

1        retail electric supplier may elect to supply its retail
2        customers with renewable energy credits from the
3        facility or facilities described in item (i) of this
4        subparagraph (H) that continue to be owned by the
5        alternative retail electric supplier.
6            (iii) The alternative retail electric supplier
7        shall notify the Agency and the applicable utility, no
8        later than February 28 of the year preceding the
9        applicable delivery year or 15 days after June 1, 2017
10        (the effective date of Public Act 99-906) this
11        amendatory Act of the 99th General Assembly, whichever
12        is later, of its election under item (ii) of this
13        subparagraph (H) to supply renewable energy credits to
14        retail customers of the utility. Such election shall
15        identify the amount of renewable energy credits to be
16        supplied by the alternative retail electric supplier
17        to the utility's retail customers and the source of the
18        renewable energy credits identified in the
19        informational filing as described in item (i) of this
20        subparagraph (H), subject to the following
21        limitations:
22                For the delivery year beginning June 1, 2018,
23            the maximum amount of renewable energy credits to
24            be supplied by an alternative retail electric
25            supplier under this subparagraph (H) shall be 68%
26            multiplied by 25% multiplied by 14.5% multiplied

 

 

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1            by the amount of metered electricity
2            (megawatt-hours) delivered by the alternative
3            retail electric supplier to Illinois retail
4            customers during the delivery year ending May 31,
5            2016.
6                For delivery years beginning June 1, 2019 and
7            each year thereafter, the maximum amount of
8            renewable energy credits to be supplied by an
9            alternative retail electric supplier under this
10            subparagraph (H) shall be 68% multiplied by 50%
11            multiplied by 16% multiplied by the amount of
12            metered electricity (megawatt-hours) delivered by
13            the alternative retail electric supplier to
14            Illinois retail customers during the delivery year
15            ending May 31, 2016, provided that the 16% value
16            shall increase by 1.5% each delivery year
17            thereafter to 25% by the delivery year beginning
18            June 1, 2025, and thereafter the 25% value shall
19            apply to each delivery year.
20            For each delivery year, the total amount of
21        renewable energy credits supplied by all alternative
22        retail electric suppliers under this subparagraph (H)
23        shall not exceed 9% of the Illinois target renewable
24        energy credit quantity. The Illinois target renewable
25        energy credit quantity for the delivery year beginning
26        June 1, 2018 is 14.5% multiplied by the total amount of

 

 

HB5134- 37 -LRB100 20041 SMS 35323 b

1        metered electricity (megawatt-hours) delivered in the
2        delivery year immediately preceding that delivery
3        year, provided that the 14.5% shall increase by 1.5%
4        each delivery year thereafter to 25% by the delivery
5        year beginning June 1, 2025, and thereafter the 25%
6        value shall apply to each delivery year.
7            If the requirements set forth in items (i) through
8        (iii) of this subparagraph (H) are met, the charges
9        that would otherwise be applicable to the retail
10        customers of the alternative retail electric supplier
11        under paragraph (6) of this subsection (c) for the
12        applicable delivery year shall be reduced by the ratio
13        of the quantity of renewable energy credits supplied by
14        the alternative retail electric supplier compared to
15        that supplier's target renewable energy credit
16        quantity. The supplier's target renewable energy
17        credit quantity for the delivery year beginning June 1,
18        2018 is 14.5% multiplied by the total amount of metered
19        electricity (megawatt-hours) delivered by the
20        alternative retail supplier in that delivery year,
21        provided that the 14.5% shall increase by 1.5% each
22        delivery year thereafter to 25% by the delivery year
23        beginning June 1, 2025, and thereafter the 25% value
24        shall apply to each delivery year.
25            On or before April 1 of each year, the Agency shall
26        annually publish a report on its website that

 

 

HB5134- 38 -LRB100 20041 SMS 35323 b

1        identifies the aggregate amount of renewable energy
2        credits supplied by alternative retail electric
3        suppliers under this subparagraph (H).
4        (I) The Agency shall design its long-term renewable
5    energy procurement plan to maximize the State's interest in
6    the health, safety, and welfare of its residents, including
7    but not limited to minimizing sulfur dioxide, nitrogen
8    oxide, particulate matter and other pollution that
9    adversely affects public health in this State, increasing
10    fuel and resource diversity in this State, enhancing the
11    reliability and resiliency of the electricity distribution
12    system in this State, meeting goals to limit carbon dioxide
13    emissions under federal or State law, and contributing to a
14    cleaner and healthier environment for the citizens of this
15    State. In order to further these legislative purposes,
16    renewable energy credits shall be eligible to be counted
17    toward the renewable energy requirements of this
18    subsection (c) if they are generated from facilities
19    located in this State. The Agency may qualify renewable
20    energy credits from facilities located in states adjacent
21    to Illinois if the generator demonstrates and the Agency
22    determines that the operation of such facility or
23    facilities will help promote the State's interest in the
24    health, safety, and welfare of its residents based on the
25    public interest criteria described above. To ensure that
26    the public interest criteria are applied to the procurement

 

 

HB5134- 39 -LRB100 20041 SMS 35323 b

1    and given full effect, the Agency's long-term procurement
2    plan shall describe in detail how each public interest
3    factor shall be considered and weighted for facilities
4    located in states adjacent to Illinois.
5        (J) In order to promote the competitive development of
6    renewable energy resources in furtherance of the State's
7    interest in the health, safety, and welfare of its
8    residents, renewable energy credits shall not be eligible
9    to be counted toward the renewable energy requirements of
10    this subsection (c) if they are sourced from a generating
11    unit whose costs were being recovered through rates
12    regulated by this State or any other state or states on or
13    after January 1, 2017. Each contract executed to purchase
14    renewable energy credits under this subsection (c) shall
15    provide for the contract's termination if the costs of the
16    generating unit supplying the renewable energy credits
17    subsequently begin to be recovered through rates regulated
18    by this State or any other state or states; and each
19    contract shall further provide that, in that event, the
20    supplier of the credits must return 110% of all payments
21    received under the contract. Amounts returned under the
22    requirements of this subparagraph (J) shall be retained by
23    the utility and all of these amounts shall be used for the
24    procurement of additional renewable energy credits from
25    new wind or new photovoltaic resources as defined in this
26    subsection (c). The long-term plan shall provide that these

 

 

HB5134- 40 -LRB100 20041 SMS 35323 b

1    renewable energy credits shall be procured in the next
2    procurement event.
3        Notwithstanding the limitations of this subparagraph
4    (J), renewable energy credits sourced from generating
5    units that are constructed, purchased, owned, or leased by
6    an electric utility as part of an approved project,
7    program, or pilot under Section 1-56 of this Act shall be
8    eligible to be counted toward the renewable energy
9    requirements of this subsection (c), regardless of how the
10    costs of these units are recovered.
11        (K) The long-term renewable resources procurement plan
12    developed by the Agency in accordance with subparagraph (A)
13    of this paragraph (1) shall include an Adjustable Block
14    program for the procurement of renewable energy credits
15    from new photovoltaic projects that are distributed
16    renewable energy generation devices or new photovoltaic
17    community renewable generation projects. The Adjustable
18    Block program shall be designed to provide a transparent
19    schedule of prices and quantities to enable the
20    photovoltaic market to scale up and for renewable energy
21    credit prices to adjust at a predictable rate over time.
22    The prices set by the Adjustable Block program can be
23    reflected as a set value or as the product of a formula.
24        The Adjustable Block program shall include for each
25    category of eligible projects: a schedule of standard block
26    purchase prices to be offered; a series of steps, with

 

 

HB5134- 41 -LRB100 20041 SMS 35323 b

1    associated nameplate capacity and purchase prices that
2    adjust from step to step; and automatic opening of the next
3    step as soon as the nameplate capacity and available
4    purchase prices for an open step are fully committed or
5    reserved. Only projects energized on or after June 1, 2017
6    shall be eligible for the Adjustable Block program. For
7    each block group the Agency shall determine the number of
8    blocks, the amount of generation capacity in each block,
9    and the purchase price for each block, provided that the
10    purchase price provided and the total amount of generation
11    in all blocks for all block groups shall be sufficient to
12    meet the goals in this subsection (c). The Agency may
13    periodically review its prior decisions establishing the
14    number of blocks, the amount of generation capacity in each
15    block, and the purchase price for each block, and may
16    propose, on an expedited basis, changes to these previously
17    set values, including but not limited to redistributing
18    these amounts and the available funds as necessary and
19    appropriate, subject to Commission approval as part of the
20    periodic plan revision process described in Section
21    16-111.5 of the Public Utilities Act. The Agency may define
22    different block sizes, purchase prices, or other distinct
23    terms and conditions for projects located in different
24    utility service territories if the Agency deems it
25    necessary to meet the goals in this subsection (c).
26        The Adjustable Block program shall include at least the

 

 

HB5134- 42 -LRB100 20041 SMS 35323 b

1    following block groups in at least the following amounts,
2    which may be adjusted upon review by the Agency and
3    approval by the Commission as described in this
4    subparagraph (K):
5            (i) At least 25% from distributed renewable energy
6        generation devices with a nameplate capacity of no more
7        than 10 kilowatts.
8            (ii) At least 25% from distributed renewable
9        energy generation devices with a nameplate capacity of
10        more than 10 kilowatts and no more than 2,000
11        kilowatts. The Agency may create sub-categories within
12        this category to account for the differences between
13        projects for small commercial customers, large
14        commercial customers, and public or non-profit
15        customers.
16            (iii) At least 25% from photovoltaic community
17        renewable generation projects.
18            (iv) The remaining 25% shall be allocated as
19        specified by the Agency in the long-term renewable
20        resources procurement plan.
21        The Adjustable Block program shall be designed to
22    ensure that renewable energy credits are procured from
23    photovoltaic distributed renewable energy generation
24    devices and new photovoltaic community renewable energy
25    generation projects in diverse locations and are not
26    concentrated in a few geographic areas.

 

 

HB5134- 43 -LRB100 20041 SMS 35323 b

1        (L) The procurement of photovoltaic renewable energy
2    credits under items (i) through (iv) of subparagraph (K) of
3    this paragraph (1) shall be subject to the following
4    contract and payment terms:
5            (i) The Agency shall procure contracts of at least
6        15 years in length.
7            (ii) For those renewable energy credits that
8        qualify and are procured under item (i) of subparagraph
9        (K) of this paragraph (1), the renewable energy credit
10        purchase price shall be paid in full by the contracting
11        utilities at the time that the facility producing the
12        renewable energy credits is interconnected at the
13        distribution system level of the utility and
14        energized. The electric utility shall receive and
15        retire all renewable energy credits generated by the
16        project for the first 15 years of operation.
17            (iii) For those renewable energy credits that
18        qualify and are procured under item (ii) and (iii) of
19        subparagraph (K) of this paragraph (1) and any
20        additional categories of distributed generation
21        included in the long-term renewable resources
22        procurement plan and approved by the Commission, 20
23        percent of the renewable energy credit purchase price
24        shall be paid by the contracting utilities at the time
25        that the facility producing the renewable energy
26        credits is interconnected at the distribution system

 

 

HB5134- 44 -LRB100 20041 SMS 35323 b

1        level of the utility and energized. The remaining
2        portion shall be paid ratably over the subsequent
3        4-year period. The electric utility shall receive and
4        retire all renewable energy credits generated by the
5        project for the first 15 years of operation.
6            (iv) Each contract shall include provisions to
7        ensure the delivery of the renewable energy credits for
8        the full term of the contract.
9            (v) The utility shall be the counterparty to the
10        contracts executed under this subparagraph (L) that
11        are approved by the Commission under the process
12        described in Section 16-111.5 of the Public Utilities
13        Act. No contract shall be executed for an amount that
14        is less than one renewable energy credit per year.
15            (vi) If, at any time, approved applications for the
16        Adjustable Block program exceed funds collected by the
17        electric utility or would cause the Agency to exceed
18        the limitation described in subparagraph (E) of this
19        paragraph (1) on the amount of renewable energy
20        resources that may be procured, then the Agency shall
21        consider future uncommitted funds to be reserved for
22        these contracts on a first-come, first-served basis,
23        with the delivery of renewable energy credits required
24        beginning at the time that the reserved funds become
25        available.
26            (vii) Nothing in this Section shall require the

 

 

HB5134- 45 -LRB100 20041 SMS 35323 b

1        utility to advance any payment or pay any amounts that
2        exceed the actual amount of revenues collected by the
3        utility under paragraph (6) of this subsection (c) and
4        subsection (k) of Section 16-108 of the Public
5        Utilities Act, and contracts executed under this
6        Section shall expressly incorporate this limitation.
7        (M) The Agency shall be authorized to retain one or
8    more experts or expert consulting firms to develop,
9    administer, implement, operate, and evaluate the
10    Adjustable Block program described in subparagraph (K) of
11    this paragraph (1), and the Agency shall retain the
12    consultant or consultants in the same manner, to the extent
13    practicable, as the Agency retains others to administer
14    provisions of this Act, including, but not limited to, the
15    procurement administrator. The selection of experts and
16    expert consulting firms and the procurement process
17    described in this subparagraph (M) are exempt from the
18    requirements of Section 20-10 of the Illinois Procurement
19    Code, under Section 20-10 of that Code. The Agency shall
20    strive to minimize administrative expenses in the
21    implementation of the Adjustable Block program.
22        The Agency and its consultant or consultants shall
23    monitor block activity, share program activity with
24    stakeholders and conduct regularly scheduled meetings to
25    discuss program activity and market conditions. If
26    necessary, the Agency may make prospective administrative

 

 

HB5134- 46 -LRB100 20041 SMS 35323 b

1    adjustments to the Adjustable Block program design, such as
2    redistributing available funds or making adjustments to
3    purchase prices as necessary to achieve the goals of this
4    subsection (c). Program modifications to any price,
5    capacity block, or other program element that do not
6    deviate from the Commission's approved value by more than
7    25% shall take effect immediately and are not subject to
8    Commission review and approval. Program modifications to
9    any price, capacity block, or other program element that
10    deviate more than 25% from the Commission's approved value
11    must be approved by the Commission as a long-term plan
12    amendment under Section 16-111.5 of the Public Utilities
13    Act. The Agency shall consider stakeholder feedback when
14    making adjustments to the Adjustable Block design and shall
15    notify stakeholders in advance of any planned changes.
16        (N) The long-term renewable resources procurement plan
17    required by this subsection (c) shall include a community
18    renewable generation program. The Agency shall establish
19    the terms, conditions, and program requirements for
20    community renewable generation projects with a goal to
21    expand renewable energy generating facility access to a
22    broader group of energy consumers, to ensure robust
23    participation opportunities for residential and small
24    commercial customers and those who cannot install
25    renewable energy on their own properties. Any plan approved
26    by the Commission shall allow subscriptions to community

 

 

HB5134- 47 -LRB100 20041 SMS 35323 b

1    renewable generation projects to be portable and
2    transferable. For purposes of this subparagraph (N),
3    "portable" means that subscriptions may be retained by the
4    subscriber even if the subscriber relocates or changes its
5    address within the same utility service territory; and
6    "transferable" means that a subscriber may assign or sell
7    subscriptions to another person within the same utility
8    service territory.
9        Electric utilities shall provide a monetary credit to a
10    subscriber's subsequent bill for service for the
11    proportional output of a community renewable generation
12    project attributable to that subscriber as specified in
13    Section 16-107.5 of the Public Utilities Act.
14        The Agency shall purchase renewable energy credits
15    from subscribed shares of photovoltaic community renewable
16    generation projects through the Adjustable Block program
17    described in subparagraph (K) of this paragraph (1) or
18    through the Illinois Solar for All Program described in
19    Section 1-56 of this Act. The electric utility shall
20    purchase any unsubscribed energy from community renewable
21    generation projects that are Qualifying Facilities ("QF")
22    under the electric utility's tariff for purchasing the
23    output from QFs under Public Utilities Regulatory Policies
24    Act of 1978.
25        The owners of and any subscribers to a community
26    renewable generation project shall not be considered

 

 

HB5134- 48 -LRB100 20041 SMS 35323 b

1    public utilities or alternative retail electricity
2    suppliers under the Public Utilities Act solely as a result
3    of their interest in or subscription to a community
4    renewable generation project and shall not be required to
5    become an alternative retail electric supplier by
6    participating in a community renewable generation project
7    with a public utility.
8        (O) For the delivery year beginning June 1, 2018, the
9    long-term renewable resources procurement plan required by
10    this subsection (c) shall provide for the Agency to procure
11    contracts to continue offering the Illinois Solar for All
12    Program described in subsection (b) of Section 1-56 of this
13    Act, and the contracts approved by the Commission shall be
14    executed by the utilities that are subject to this
15    subsection (c). The long-term renewable resources
16    procurement plan shall allocate 5% of the funds available
17    under the plan for the applicable delivery year, or
18    $10,000,000 per delivery year, whichever is greater, to
19    fund the programs, and the plan shall determine the amount
20    of funding to be apportioned to the programs identified in
21    subsection (b) of Section 1-56 of this Act; provided that
22    for the delivery years beginning June 1, 2017, June 1,
23    2021, and June 1, 2025, the long-term renewable resources
24    procurement plan shall allocate 10% of the funds available
25    under the plan for the applicable delivery year, or
26    $20,000,000 per delivery year, whichever is greater, and

 

 

HB5134- 49 -LRB100 20041 SMS 35323 b

1    $10,000,000 of such funds in such year shall be used by an
2    electric utility that serves more than 3,000,000 retail
3    customers in the State to implement a Commission-approved
4    plan under Section 16-108.12 of the Public Utilities Act.
5    In making the determinations required under this
6    subparagraph (O), the Commission shall consider the
7    experience and performance under the programs and any
8    evaluation reports. The Commission shall also provide for
9    an independent evaluation of those programs on a periodic
10    basis that are funded under this subparagraph (O).
11        (2) (Blank).
12        (3) (Blank).
13        (4) The electric utility shall retire all renewable
14    energy credits used to comply with the standard.
15        (5) Beginning with the 2010 delivery year and ending
16    June 1, 2017, an electric utility subject to this
17    subsection (c) shall apply the lesser of the maximum
18    alternative compliance payment rate or the most recent
19    estimated alternative compliance payment rate for its
20    service territory for the corresponding compliance period,
21    established pursuant to subsection (d) of Section 16-115D
22    of the Public Utilities Act to its retail customers that
23    take service pursuant to the electric utility's hourly
24    pricing tariff or tariffs. The electric utility shall
25    retain all amounts collected as a result of the application
26    of the alternative compliance payment rate or rates to such

 

 

HB5134- 50 -LRB100 20041 SMS 35323 b

1    customers, and, beginning in 2011, the utility shall
2    include in the information provided under item (1) of
3    subsection (d) of Section 16-111.5 of the Public Utilities
4    Act the amounts collected under the alternative compliance
5    payment rate or rates for the prior year ending May 31.
6    Notwithstanding any limitation on the procurement of
7    renewable energy resources imposed by item (2) of this
8    subsection (c), the Agency shall increase its spending on
9    the purchase of renewable energy resources to be procured
10    by the electric utility for the next plan year by an amount
11    equal to the amounts collected by the utility under the
12    alternative compliance payment rate or rates in the prior
13    year ending May 31.
14        (6) The electric utility shall be entitled to recover
15    all of its costs associated with the procurement of
16    renewable energy credits under plans approved under this
17    Section and Section 16-111.5 of the Public Utilities Act.
18    These costs shall include associated reasonable expenses
19    for implementing the procurement programs, including, but
20    not limited to, the costs of administering and evaluating
21    the Adjustable Block program, through an automatic
22    adjustment clause tariff in accordance with subsection (k)
23    of Section 16-108 of the Public Utilities Act.
24        (7) Renewable energy credits procured from new
25    photovoltaic projects or new distributed renewable energy
26    generation devices under this Section after June 1, 2017

 

 

HB5134- 51 -LRB100 20041 SMS 35323 b

1    (the effective date of Public Act 99-906) this amendatory
2    Act of the 99th General Assembly must be procured from
3    devices installed by a qualified person in compliance with
4    the requirements of Section 16-128A of the Public Utilities
5    Act and any rules or regulations adopted thereunder.
6        In meeting the renewable energy requirements of this
7    subsection (c), to the extent feasible and consistent with
8    State and federal law, the renewable energy credit
9    procurements, Adjustable Block solar program, and
10    community renewable generation program shall provide
11    employment opportunities for all segments of the
12    population and workforce, including minority-owned and
13    female-owned business enterprises, and shall not,
14    consistent with State and federal law, discriminate based
15    on race or socioeconomic status.
16    (d) Clean coal portfolio standard.
17        (1) The procurement plans shall include electricity
18    generated using clean coal. Each utility shall enter into
19    one or more sourcing agreements with the initial clean coal
20    facility, as provided in paragraph (3) of this subsection
21    (d), covering electricity generated by the initial clean
22    coal facility representing at least 5% of each utility's
23    total supply to serve the load of eligible retail customers
24    in 2015 and each year thereafter, as described in paragraph
25    (3) of this subsection (d), subject to the limits specified
26    in paragraph (2) of this subsection (d). It is the goal of

 

 

HB5134- 52 -LRB100 20041 SMS 35323 b

1    the State that by January 1, 2025, 25% of the electricity
2    used in the State shall be generated by cost-effective
3    clean coal facilities. For purposes of this subsection (d),
4    "cost-effective" means that the expenditures pursuant to
5    such sourcing agreements do not cause the limit stated in
6    paragraph (2) of this subsection (d) to be exceeded and do
7    not exceed cost-based benchmarks, which shall be developed
8    to assess all expenditures pursuant to such sourcing
9    agreements covering electricity generated by clean coal
10    facilities, other than the initial clean coal facility, by
11    the procurement administrator, in consultation with the
12    Commission staff, Agency staff, and the procurement
13    monitor and shall be subject to Commission review and
14    approval.
15        A utility party to a sourcing agreement shall
16    immediately retire any emission credits that it receives in
17    connection with the electricity covered by such agreement.
18        Utilities shall maintain adequate records documenting
19    the purchases under the sourcing agreement to comply with
20    this subsection (d) and shall file an accounting with the
21    load forecast that must be filed with the Agency by July 15
22    of each year, in accordance with subsection (d) of Section
23    16-111.5 of the Public Utilities Act.
24        A utility shall be deemed to have complied with the
25    clean coal portfolio standard specified in this subsection
26    (d) if the utility enters into a sourcing agreement as

 

 

HB5134- 53 -LRB100 20041 SMS 35323 b

1    required by this subsection (d).
2        (2) For purposes of this subsection (d), the required
3    execution of sourcing agreements with the initial clean
4    coal facility for a particular year shall be measured as a
5    percentage of the actual amount of electricity
6    (megawatt-hours) supplied by the electric utility to
7    eligible retail customers in the planning year ending
8    immediately prior to the agreement's execution. For
9    purposes of this subsection (d), the amount paid per
10    kilowatthour means the total amount paid for electric
11    service expressed on a per kilowatthour basis. For purposes
12    of this subsection (d), the total amount paid for electric
13    service includes without limitation amounts paid for
14    supply, transmission, distribution, surcharges and add-on
15    taxes.
16        Notwithstanding the requirements of this subsection
17    (d), the total amount paid under sourcing agreements with
18    clean coal facilities pursuant to the procurement plan for
19    any given year shall be reduced by an amount necessary to
20    limit the annual estimated average net increase due to the
21    costs of these resources included in the amounts paid by
22    eligible retail customers in connection with electric
23    service to:
24            (A) in 2010, no more than 0.5% of the amount paid
25        per kilowatthour by those customers during the year
26        ending May 31, 2009;

 

 

HB5134- 54 -LRB100 20041 SMS 35323 b

1            (B) in 2011, the greater of an additional 0.5% of
2        the amount paid per kilowatthour by those customers
3        during the year ending May 31, 2010 or 1% of the amount
4        paid per kilowatthour by those customers during the
5        year ending May 31, 2009;
6            (C) in 2012, the greater of an additional 0.5% of
7        the amount paid per kilowatthour by those customers
8        during the year ending May 31, 2011 or 1.5% of the
9        amount paid per kilowatthour by those customers during
10        the year ending May 31, 2009;
11            (D) in 2013, the greater of an additional 0.5% of
12        the amount paid per kilowatthour by those customers
13        during the year ending May 31, 2012 or 2% of the amount
14        paid per kilowatthour by those customers during the
15        year ending May 31, 2009; and
16            (E) thereafter, the total amount paid under
17        sourcing agreements with clean coal facilities
18        pursuant to the procurement plan for any single year
19        shall be reduced by an amount necessary to limit the
20        estimated average net increase due to the cost of these
21        resources included in the amounts paid by eligible
22        retail customers in connection with electric service
23        to no more than the greater of (i) 2.015% of the amount
24        paid per kilowatthour by those customers during the
25        year ending May 31, 2009 or (ii) the incremental amount
26        per kilowatthour paid for these resources in 2013.

 

 

HB5134- 55 -LRB100 20041 SMS 35323 b

1        These requirements may be altered only as provided by
2        statute.
3        No later than June 30, 2015, the Commission shall
4    review the limitation on the total amount paid under
5    sourcing agreements, if any, with clean coal facilities
6    pursuant to this subsection (d) and report to the General
7    Assembly its findings as to whether that limitation unduly
8    constrains the amount of electricity generated by
9    cost-effective clean coal facilities that is covered by
10    sourcing agreements.
11        (3) Initial clean coal facility. In order to promote
12    development of clean coal facilities in Illinois, each
13    electric utility subject to this Section shall execute a
14    sourcing agreement to source electricity from a proposed
15    clean coal facility in Illinois (the "initial clean coal
16    facility") that will have a nameplate capacity of at least
17    500 MW when commercial operation commences, that has a
18    final Clean Air Act permit on June 1, 2009 (the effective
19    date of Public Act 95-1027) this amendatory Act of the 95th
20    General Assembly, and that will meet the definition of
21    clean coal facility in Section 1-10 of this Act when
22    commercial operation commences. The sourcing agreements
23    with this initial clean coal facility shall be subject to
24    both approval of the initial clean coal facility by the
25    General Assembly and satisfaction of the requirements of
26    paragraph (4) of this subsection (d) and shall be executed

 

 

HB5134- 56 -LRB100 20041 SMS 35323 b

1    within 90 days after any such approval by the General
2    Assembly. The Agency and the Commission shall have
3    authority to inspect all books and records associated with
4    the initial clean coal facility during the term of such a
5    sourcing agreement. A utility's sourcing agreement for
6    electricity produced by the initial clean coal facility
7    shall include:
8            (A) a formula contractual price (the "contract
9        price") approved pursuant to paragraph (4) of this
10        subsection (d), which shall:
11                (i) be determined using a cost of service
12            methodology employing either a level or deferred
13            capital recovery component, based on a capital
14            structure consisting of 45% equity and 55% debt,
15            and a return on equity as may be approved by the
16            Federal Energy Regulatory Commission, which in any
17            case may not exceed the lower of 11.5% or the rate
18            of return approved by the General Assembly
19            pursuant to paragraph (4) of this subsection (d);
20            and
21                (ii) provide that all miscellaneous net
22            revenue, including but not limited to net revenue
23            from the sale of emission allowances, if any,
24            substitute natural gas, if any, grants or other
25            support provided by the State of Illinois or the
26            United States Government, firm transmission

 

 

HB5134- 57 -LRB100 20041 SMS 35323 b

1            rights, if any, by-products produced by the
2            facility, energy or capacity derived from the
3            facility and not covered by a sourcing agreement
4            pursuant to paragraph (3) of this subsection (d) or
5            item (5) of subsection (d) of Section 16-115 of the
6            Public Utilities Act, whether generated from the
7            synthesis gas derived from coal, from SNG, or from
8            natural gas, shall be credited against the revenue
9            requirement for this initial clean coal facility;
10            (B) power purchase provisions, which shall:
11                (i) provide that the utility party to such
12            sourcing agreement shall pay the contract price
13            for electricity delivered under such sourcing
14            agreement;
15                (ii) require delivery of electricity to the
16            regional transmission organization market of the
17            utility that is party to such sourcing agreement;
18                (iii) require the utility party to such
19            sourcing agreement to buy from the initial clean
20            coal facility in each hour an amount of energy
21            equal to all clean coal energy made available from
22            the initial clean coal facility during such hour
23            times a fraction, the numerator of which is such
24            utility's retail market sales of electricity
25            (expressed in kilowatthours sold) in the State
26            during the prior calendar month and the

 

 

HB5134- 58 -LRB100 20041 SMS 35323 b

1            denominator of which is the total retail market
2            sales of electricity (expressed in kilowatthours
3            sold) in the State by utilities during such prior
4            month and the sales of electricity (expressed in
5            kilowatthours sold) in the State by alternative
6            retail electric suppliers during such prior month
7            that are subject to the requirements of this
8            subsection (d) and paragraph (5) of subsection (d)
9            of Section 16-115 of the Public Utilities Act,
10            provided that the amount purchased by the utility
11            in any year will be limited by paragraph (2) of
12            this subsection (d); and
13                (iv) be considered pre-existing contracts in
14            such utility's procurement plans for eligible
15            retail customers;
16            (C) contract for differences provisions, which
17        shall:
18                (i) require the utility party to such sourcing
19            agreement to contract with the initial clean coal
20            facility in each hour with respect to an amount of
21            energy equal to all clean coal energy made
22            available from the initial clean coal facility
23            during such hour times a fraction, the numerator of
24            which is such utility's retail market sales of
25            electricity (expressed in kilowatthours sold) in
26            the utility's service territory in the State

 

 

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1            during the prior calendar month and the
2            denominator of which is the total retail market
3            sales of electricity (expressed in kilowatthours
4            sold) in the State by utilities during such prior
5            month and the sales of electricity (expressed in
6            kilowatthours sold) in the State by alternative
7            retail electric suppliers during such prior month
8            that are subject to the requirements of this
9            subsection (d) and paragraph (5) of subsection (d)
10            of Section 16-115 of the Public Utilities Act,
11            provided that the amount paid by the utility in any
12            year will be limited by paragraph (2) of this
13            subsection (d);
14                (ii) provide that the utility's payment
15            obligation in respect of the quantity of
16            electricity determined pursuant to the preceding
17            clause (i) shall be limited to an amount equal to
18            (1) the difference between the contract price
19            determined pursuant to subparagraph (A) of
20            paragraph (3) of this subsection (d) and the
21            day-ahead price for electricity delivered to the
22            regional transmission organization market of the
23            utility that is party to such sourcing agreement
24            (or any successor delivery point at which such
25            utility's supply obligations are financially
26            settled on an hourly basis) (the "reference

 

 

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1            price") on the day preceding the day on which the
2            electricity is delivered to the initial clean coal
3            facility busbar, multiplied by (2) the quantity of
4            electricity determined pursuant to the preceding
5            clause (i); and
6                (iii) not require the utility to take physical
7            delivery of the electricity produced by the
8            facility;
9            (D) general provisions, which shall:
10                (i) specify a term of no more than 30 years,
11            commencing on the commercial operation date of the
12            facility;
13                (ii) provide that utilities shall maintain
14            adequate records documenting purchases under the
15            sourcing agreements entered into to comply with
16            this subsection (d) and shall file an accounting
17            with the load forecast that must be filed with the
18            Agency by July 15 of each year, in accordance with
19            subsection (d) of Section 16-111.5 of the Public
20            Utilities Act;
21                (iii) provide that all costs associated with
22            the initial clean coal facility will be
23            periodically reported to the Federal Energy
24            Regulatory Commission and to purchasers in
25            accordance with applicable laws governing
26            cost-based wholesale power contracts;

 

 

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1                (iv) permit the Illinois Power Agency to
2            assume ownership of the initial clean coal
3            facility, without monetary consideration and
4            otherwise on reasonable terms acceptable to the
5            Agency, if the Agency so requests no less than 3
6            years prior to the end of the stated contract term;
7                (v) require the owner of the initial clean coal
8            facility to provide documentation to the
9            Commission each year, starting in the facility's
10            first year of commercial operation, accurately
11            reporting the quantity of carbon emissions from
12            the facility that have been captured and
13            sequestered and report any quantities of carbon
14            released from the site or sites at which carbon
15            emissions were sequestered in prior years, based
16            on continuous monitoring of such sites. If, in any
17            year after the first year of commercial operation,
18            the owner of the facility fails to demonstrate that
19            the initial clean coal facility captured and
20            sequestered at least 50% of the total carbon
21            emissions that the facility would otherwise emit
22            or that sequestration of emissions from prior
23            years has failed, resulting in the release of
24            carbon dioxide into the atmosphere, the owner of
25            the facility must offset excess emissions. Any
26            such carbon offsets must be permanent, additional,

 

 

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1            verifiable, real, located within the State of
2            Illinois, and legally and practicably enforceable.
3            The cost of such offsets for the facility that are
4            not recoverable shall not exceed $15 million in any
5            given year. No costs of any such purchases of
6            carbon offsets may be recovered from a utility or
7            its customers. All carbon offsets purchased for
8            this purpose and any carbon emission credits
9            associated with sequestration of carbon from the
10            facility must be permanently retired. The initial
11            clean coal facility shall not forfeit its
12            designation as a clean coal facility if the
13            facility fails to fully comply with the applicable
14            carbon sequestration requirements in any given
15            year, provided the requisite offsets are
16            purchased. However, the Attorney General, on
17            behalf of the People of the State of Illinois, may
18            specifically enforce the facility's sequestration
19            requirement and the other terms of this contract
20            provision. Compliance with the sequestration
21            requirements and offset purchase requirements
22            specified in paragraph (3) of this subsection (d)
23            shall be reviewed annually by an independent
24            expert retained by the owner of the initial clean
25            coal facility, with the advance written approval
26            of the Attorney General. The Commission may, in the

 

 

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1            course of the review specified in item (vii),
2            reduce the allowable return on equity for the
3            facility if the facility willfully wilfully fails
4            to comply with the carbon capture and
5            sequestration requirements set forth in this item
6            (v);
7                (vi) include limits on, and accordingly
8            provide for modification of, the amount the
9            utility is required to source under the sourcing
10            agreement consistent with paragraph (2) of this
11            subsection (d);
12                (vii) require Commission review: (1) to
13            determine the justness, reasonableness, and
14            prudence of the inputs to the formula referenced in
15            subparagraphs (A)(i) through (A)(iii) of paragraph
16            (3) of this subsection (d), prior to an adjustment
17            in those inputs including, without limitation, the
18            capital structure and return on equity, fuel
19            costs, and other operations and maintenance costs
20            and (2) to approve the costs to be passed through
21            to customers under the sourcing agreement by which
22            the utility satisfies its statutory obligations.
23            Commission review shall occur no less than every 3
24            years, regardless of whether any adjustments have
25            been proposed, and shall be completed within 9
26            months;

 

 

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1                (viii) limit the utility's obligation to such
2            amount as the utility is allowed to recover through
3            tariffs filed with the Commission, provided that
4            neither the clean coal facility nor the utility
5            waives any right to assert federal pre-emption or
6            any other argument in response to a purported
7            disallowance of recovery costs;
8                (ix) limit the utility's or alternative retail
9            electric supplier's obligation to incur any
10            liability until such time as the facility is in
11            commercial operation and generating power and
12            energy and such power and energy is being delivered
13            to the facility busbar;
14                (x) provide that the owner or owners of the
15            initial clean coal facility, which is the
16            counterparty to such sourcing agreement, shall
17            have the right from time to time to elect whether
18            the obligations of the utility party thereto shall
19            be governed by the power purchase provisions or the
20            contract for differences provisions;
21                (xi) append documentation showing that the
22            formula rate and contract, insofar as they relate
23            to the power purchase provisions, have been
24            approved by the Federal Energy Regulatory
25            Commission pursuant to Section 205 of the Federal
26            Power Act;

 

 

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1                (xii) provide that any changes to the terms of
2            the contract, insofar as such changes relate to the
3            power purchase provisions, are subject to review
4            under the public interest standard applied by the
5            Federal Energy Regulatory Commission pursuant to
6            Sections 205 and 206 of the Federal Power Act; and
7                (xiii) conform with customary lender
8            requirements in power purchase agreements used as
9            the basis for financing non-utility generators.
10        (4) Effective date of sourcing agreements with the
11    initial clean coal facility.
12        Any proposed sourcing agreement with the initial clean
13    coal facility shall not become effective unless the
14    following reports are prepared and submitted and
15    authorizations and approvals obtained:
16            (i) Facility cost report. The owner of the initial
17        clean coal facility shall submit to the Commission, the
18        Agency, and the General Assembly a front-end
19        engineering and design study, a facility cost report,
20        method of financing (including but not limited to
21        structure and associated costs), and an operating and
22        maintenance cost quote for the facility (collectively
23        "facility cost report"), which shall be prepared in
24        accordance with the requirements of this paragraph (4)
25        of subsection (d) of this Section, and shall provide
26        the Commission and the Agency access to the work

 

 

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1        papers, relied upon documents, and any other backup
2        documentation related to the facility cost report.
3            (ii) Commission report. Within 6 months following
4        receipt of the facility cost report, the Commission, in
5        consultation with the Agency, shall submit a report to
6        the General Assembly setting forth its analysis of the
7        facility cost report. Such report shall include, but
8        not be limited to, a comparison of the costs associated
9        with electricity generated by the initial clean coal
10        facility to the costs associated with electricity
11        generated by other types of generation facilities, an
12        analysis of the rate impacts on residential and small
13        business customers over the life of the sourcing
14        agreements, and an analysis of the likelihood that the
15        initial clean coal facility will commence commercial
16        operation by and be delivering power to the facility's
17        busbar by 2016. To assist in the preparation of its
18        report, the Commission, in consultation with the
19        Agency, may hire one or more experts or consultants,
20        the costs of which shall be paid for by the owner of
21        the initial clean coal facility. The Commission and
22        Agency may begin the process of selecting such experts
23        or consultants prior to receipt of the facility cost
24        report.
25            (iii) General Assembly approval. The proposed
26        sourcing agreements shall not take effect unless,

 

 

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1        based on the facility cost report and the Commission's
2        report, the General Assembly enacts authorizing
3        legislation approving (A) the projected price, stated
4        in cents per kilowatthour, to be charged for
5        electricity generated by the initial clean coal
6        facility, (B) the projected impact on residential and
7        small business customers' bills over the life of the
8        sourcing agreements, and (C) the maximum allowable
9        return on equity for the project; and
10            (iv) Commission review. If the General Assembly
11        enacts authorizing legislation pursuant to
12        subparagraph (iii) approving a sourcing agreement, the
13        Commission shall, within 90 days of such enactment,
14        complete a review of such sourcing agreement. During
15        such time period, the Commission shall implement any
16        directive of the General Assembly, resolve any
17        disputes between the parties to the sourcing agreement
18        concerning the terms of such agreement, approve the
19        form of such agreement, and issue an order finding that
20        the sourcing agreement is prudent and reasonable.
21        The facility cost report shall be prepared as follows:
22            (A) The facility cost report shall be prepared by
23        duly licensed engineering and construction firms
24        detailing the estimated capital costs payable to one or
25        more contractors or suppliers for the engineering,
26        procurement and construction of the components

 

 

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1        comprising the initial clean coal facility and the
2        estimated costs of operation and maintenance of the
3        facility. The facility cost report shall include:
4                (i) an estimate of the capital cost of the core
5            plant based on one or more front end engineering
6            and design studies for the gasification island and
7            related facilities. The core plant shall include
8            all civil, structural, mechanical, electrical,
9            control, and safety systems.
10                (ii) an estimate of the capital cost of the
11            balance of the plant, including any capital costs
12            associated with sequestration of carbon dioxide
13            emissions and all interconnects and interfaces
14            required to operate the facility, such as
15            transmission of electricity, construction or
16            backfeed power supply, pipelines to transport
17            substitute natural gas or carbon dioxide, potable
18            water supply, natural gas supply, water supply,
19            water discharge, landfill, access roads, and coal
20            delivery.
21            The quoted construction costs shall be expressed
22        in nominal dollars as of the date that the quote is
23        prepared and shall include capitalized financing costs
24        during construction, taxes, insurance, and other
25        owner's costs, and an assumed escalation in materials
26        and labor beyond the date as of which the construction

 

 

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1        cost quote is expressed.
2            (B) The front end engineering and design study for
3        the gasification island and the cost study for the
4        balance of plant shall include sufficient design work
5        to permit quantification of major categories of
6        materials, commodities and labor hours, and receipt of
7        quotes from vendors of major equipment required to
8        construct and operate the clean coal facility.
9            (C) The facility cost report shall also include an
10        operating and maintenance cost quote that will provide
11        the estimated cost of delivered fuel, personnel,
12        maintenance contracts, chemicals, catalysts,
13        consumables, spares, and other fixed and variable
14        operations and maintenance costs. The delivered fuel
15        cost estimate will be provided by a recognized third
16        party expert or experts in the fuel and transportation
17        industries. The balance of the operating and
18        maintenance cost quote, excluding delivered fuel
19        costs, will be developed based on the inputs provided
20        by duly licensed engineering and construction firms
21        performing the construction cost quote, potential
22        vendors under long-term service agreements and plant
23        operating agreements, or recognized third party plant
24        operator or operators.
25            The operating and maintenance cost quote
26        (including the cost of the front end engineering and

 

 

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1        design study) shall be expressed in nominal dollars as
2        of the date that the quote is prepared and shall
3        include taxes, insurance, and other owner's costs, and
4        an assumed escalation in materials and labor beyond the
5        date as of which the operating and maintenance cost
6        quote is expressed.
7            (D) The facility cost report shall also include an
8        analysis of the initial clean coal facility's ability
9        to deliver power and energy into the applicable
10        regional transmission organization markets and an
11        analysis of the expected capacity factor for the
12        initial clean coal facility.
13            (E) Amounts paid to third parties unrelated to the
14        owner or owners of the initial clean coal facility to
15        prepare the core plant construction cost quote,
16        including the front end engineering and design study,
17        and the operating and maintenance cost quote will be
18        reimbursed through Coal Development Bonds.
19        (5) Re-powering and retrofitting coal-fired power
20    plants previously owned by Illinois utilities to qualify as
21    clean coal facilities. During the 2009 procurement
22    planning process and thereafter, the Agency and the
23    Commission shall consider sourcing agreements covering
24    electricity generated by power plants that were previously
25    owned by Illinois utilities and that have been or will be
26    converted into clean coal facilities, as defined by Section

 

 

HB5134- 71 -LRB100 20041 SMS 35323 b

1    1-10 of this Act. Pursuant to such procurement planning
2    process, the owners of such facilities may propose to the
3    Agency sourcing agreements with utilities and alternative
4    retail electric suppliers required to comply with
5    subsection (d) of this Section and item (5) of subsection
6    (d) of Section 16-115 of the Public Utilities Act, covering
7    electricity generated by such facilities. In the case of
8    sourcing agreements that are power purchase agreements,
9    the contract price for electricity sales shall be
10    established on a cost of service basis. In the case of
11    sourcing agreements that are contracts for differences,
12    the contract price from which the reference price is
13    subtracted shall be established on a cost of service basis.
14    The Agency and the Commission may approve any such utility
15    sourcing agreements that do not exceed cost-based
16    benchmarks developed by the procurement administrator, in
17    consultation with the Commission staff, Agency staff and
18    the procurement monitor, subject to Commission review and
19    approval. The Commission shall have authority to inspect
20    all books and records associated with these clean coal
21    facilities during the term of any such contract.
22        (6) Costs incurred under this subsection (d) or
23    pursuant to a contract entered into under this subsection
24    (d) shall be deemed prudently incurred and reasonable in
25    amount and the electric utility shall be entitled to full
26    cost recovery pursuant to the tariffs filed with the

 

 

HB5134- 72 -LRB100 20041 SMS 35323 b

1    Commission.
2    (d-5) Zero emission standard.
3        (1) Beginning with the delivery year commencing on June
4    1, 2017, the Agency shall, for electric utilities that
5    serve at least 100,000 retail customers in this State,
6    procure contracts with zero emission facilities that are
7    reasonably capable of generating cost-effective zero
8    emission credits in an amount approximately equal to 16% of
9    the actual amount of electricity delivered by each electric
10    utility to retail customers in the State during calendar
11    year 2014. For an electric utility serving fewer than
12    100,000 retail customers in this State that requested,
13    under Section 16-111.5 of the Public Utilities Act, that
14    the Agency procure power and energy for all or a portion of
15    the utility's Illinois load for the delivery year
16    commencing June 1, 2016, the Agency shall procure contracts
17    with zero emission facilities that are reasonably capable
18    of generating cost-effective zero emission credits in an
19    amount approximately equal to 16% of the portion of power
20    and energy to be procured by the Agency for the utility.
21    The duration of the contracts procured under this
22    subsection (d-5) shall be for a term of 10 years ending May
23    31, 2027. The quantity of zero emission credits to be
24    procured under the contracts shall be all of the zero
25    emission credits generated by the zero emission facility in
26    each delivery year; however, if the zero emission facility

 

 

HB5134- 73 -LRB100 20041 SMS 35323 b

1    is owned by more than one entity, then the quantity of zero
2    emission credits to be procured under the contracts shall
3    be the amount of zero emission credits that are generated
4    from the portion of the zero emission facility that is
5    owned by the winning supplier.
6        The 16% value identified in this paragraph (1) is the
7    average of the percentage targets in subparagraph (B) of
8    paragraph (1) of subsection (c) of Section 1-75 of this Act
9    for the 5 delivery years beginning June 1, 2017.
10        The procurement process shall be subject to the
11    following provisions:
12            (A) Those zero emission facilities that intend to
13        participate in the procurement shall submit to the
14        Agency the following eligibility information for each
15        zero emission facility on or before the date
16        established by the Agency:
17                (i) the in-service date and remaining useful
18            life of the zero emission facility;
19                (ii) the amount of power generated annually
20            for each of the years 2005 through 2015, and the
21            projected zero emission credits to be generated
22            over the remaining useful life of the zero emission
23            facility, which shall be used to determine the
24            capability of each facility;
25                (iii) the annual zero emission facility cost
26            projections, expressed on a per megawatthour

 

 

HB5134- 74 -LRB100 20041 SMS 35323 b

1            basis, over the next 6 delivery years, which shall
2            include the following: operation and maintenance
3            expenses; fully allocated overhead costs, which
4            shall be allocated using the methodology developed
5            by the Institute for Nuclear Power Operations;
6            fuel expenditures; non-fuel capital expenditures;
7            spent fuel expenditures; a return on working
8            capital; the cost of operational and market risks
9            that could be avoided by ceasing operation; and any
10            other costs necessary for continued operations,
11            provided that "necessary" means, for purposes of
12            this item (iii), that the costs could reasonably be
13            avoided only by ceasing operations of the zero
14            emission facility; and
15                (iv) a commitment to continue operating, for
16            the duration of the contract or contracts executed
17            under the procurement held under this subsection
18            (d-5), the zero emission facility that produces
19            the zero emission credits to be procured in the
20            procurement.
21        The information described in item (iii) of this
22    subparagraph (A) may be submitted on a confidential basis
23    and shall be treated and maintained by the Agency, the
24    procurement administrator, and the Commission as
25    confidential and proprietary and exempt from disclosure
26    under subparagraphs (a) and (g) of paragraph (1) of Section

 

 

HB5134- 75 -LRB100 20041 SMS 35323 b

1    7 of the Freedom of Information Act. The Office of Attorney
2    General shall have access to, and maintain the
3    confidentiality of, such information pursuant to Section
4    6.5 of the Attorney General Act.
5            (B) The price for each zero emission credit
6        procured under this subsection (d-5) for each delivery
7        year shall be in an amount that equals the Social Cost
8        of Carbon, expressed on a price per megawatthour basis.
9        However, to ensure that the procurement remains
10        affordable to retail customers in this State if
11        electricity prices increase, the price in an
12        applicable delivery year shall be reduced below the
13        Social Cost of Carbon by the amount ("Price
14        Adjustment") by which the market price index for the
15        applicable delivery year exceeds the baseline market
16        price index for the consecutive 12-month period ending
17        May 31, 2016. If the Price Adjustment is greater than
18        or equal to the Social Cost of Carbon in an applicable
19        delivery year, then no payments shall be due in that
20        delivery year. The components of this calculation are
21        defined as follows:
22                (i) Social Cost of Carbon: The Social Cost of
23            Carbon is $16.50 per megawatthour, which is based
24            on the U.S. Interagency Working Group on Social
25            Cost of Carbon's price in the August 2016 Technical
26            Update using a 3% discount rate, adjusted for

 

 

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1            inflation for each year of the program. Beginning
2            with the delivery year commencing June 1, 2023, the
3            price per megawatthour shall increase by $1 per
4            megawatthour, and continue to increase by an
5            additional $1 per megawatthour each delivery year
6            thereafter.
7                (ii) Baseline market price index: The baseline
8            market price index for the consecutive 12-month
9            period ending May 31, 2016 is $31.40 per
10            megawatthour, which is based on the sum of (aa) the
11            average day-ahead energy price across all hours of
12            such 12-month period at the PJM Interconnection
13            LLC Northern Illinois Hub, (bb) 50% multiplied by
14            the Base Residual Auction, or its successor,
15            capacity price for the rest of the RTO zone group
16            determined by PJM Interconnection LLC, divided by
17            24 hours per day, and (cc) 50% multiplied by the
18            Planning Resource Auction, or its successor,
19            capacity price for Zone 4 determined by the
20            Midcontinent Independent System Operator, Inc.,
21            divided by 24 hours per day.
22                (iii) Market price index: The market price
23            index for a delivery year shall be the sum of
24            projected energy prices and projected capacity
25            prices determined as follows:
26                    (aa) Projected energy prices: the

 

 

HB5134- 77 -LRB100 20041 SMS 35323 b

1                projected energy prices for the applicable
2                delivery year shall be calculated once for the
3                year using the forward market price for the PJM
4                Interconnection, LLC Northern Illinois Hub.
5                The forward market price shall be calculated as
6                follows: the energy forward prices for each
7                month of the applicable delivery year averaged
8                for each trade date during the calendar year
9                immediately preceding that delivery year to
10                produce a single energy forward price for the
11                delivery year. The forward market price
12                calculation shall use data published by the
13                Intercontinental Exchange, or its successor.
14                    (bb) Projected capacity prices:
15                        (I) For the delivery year years
16                    commencing June 1, 2017, June 1, 2018, and
17                    June 1, 2019, the projected capacity price
18                    shall be equal to the sum of (1) 50%
19                    multiplied by the Base Residual Auction,
20                    or its successor, price for the rest of the
21                    RTO zone group as determined by PJM
22                    Interconnection LLC, divided by 24 hours
23                    per day and, (2) 50% multiplied by the
24                    resource auction price determined in the
25                    resource auction administered by the
26                    Midcontinent Independent System Operator,

 

 

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1                    Inc., in which the largest percentage of
2                    load cleared for Local Resource Zone 4,
3                    divided by 24 hours per day, and where such
4                    price is determined by the Midcontinent
5                    Independent System Operator, Inc.
6                        (I-5) For the delivery year commencing
7                    June 1, 2019, the projected capacity price
8                    shall be equal to the sum of (1) 50%
9                    multiplied by the Base Residual Auction,
10                    or its successor, price for the rest of the
11                    RTO zone group as determined by PJM
12                    Interconnection LLC, divided by 24 hours
13                    per day and (2) 50% multiplied by the
14                    weighted average price for capacity in
15                    capacity contracts awarded in procurement
16                    events conducted by the Agency under
17                    subsection (b-5) of Section 16-111.5 of
18                    the Public Utilities Act, divided by 24
19                    hours per day, with such price to be
20                    determined by the Agency.
21                        (II) For the delivery year commencing
22                    June 1, 2020, and each year thereafter, the
23                    projected capacity price shall be equal to
24                    the sum of (1) 50% multiplied by the Base
25                    Residual Auction, or its successor, price
26                    for the ComEd zone as determined by PJM

 

 

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1                    Interconnection LLC, divided by 24 hours
2                    per day, and (2) 50% multiplied by the
3                    weighted average price for capacity in
4                    capacity contracts awarded in procurement
5                    events conducted by the Agency under
6                    subsection (b-5) of Section 16-111.5 of
7                    the Public Utilities Act, divided by 24
8                    hours per day, with such price to be
9                    determined by the Agency 50% multiplied by
10                    the resource auction price determined in
11                    the resource auction administered by the
12                    Midcontinent Independent System Operator,
13                    Inc., in which the largest percentage of
14                    load cleared for Local Resource Zone 4,
15                    divided by 24 hours per day, and where such
16                    price is determined by the Midcontinent
17                    Independent System Operator, Inc.
18            For purposes of this subsection (d-5):
19                "Rest of the RTO" and "ComEd Zone" shall have
20            the meaning ascribed to them by PJM
21            Interconnection, LLC.
22                "RTO" means regional transmission
23            organization.
24            (C) No later than 45 days after June 1, 2017 (the
25        effective date of Public Act 99-906) this amendatory
26        Act of the 99th General Assembly, the Agency shall

 

 

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1        publish its proposed zero emission standard
2        procurement plan. The plan shall be consistent with the
3        provisions of this paragraph (1) and shall provide that
4        winning bids shall be selected based on public interest
5        criteria that include, but are not limited to,
6        minimizing carbon dioxide emissions that result from
7        electricity consumed in Illinois and minimizing sulfur
8        dioxide, nitrogen oxide, and particulate matter
9        emissions that adversely affect the citizens of this
10        State. In particular, the selection of winning bids
11        shall take into account the incremental environmental
12        benefits resulting from the procurement, such as any
13        existing environmental benefits that are preserved by
14        the procurements held under Public Act 99-906 this
15        amendatory Act of the 99th General Assembly and would
16        cease to exist if the procurements were not held,
17        including the preservation of zero emission
18        facilities. The plan shall also describe in detail how
19        each public interest factor shall be considered and
20        weighted in the bid selection process to ensure that
21        the public interest criteria are applied to the
22        procurement and given full effect.
23            For purposes of developing the plan, the Agency
24        shall consider any reports issued by a State agency,
25        board, or commission under House Resolution 1146 of the
26        98th General Assembly and paragraph (4) of subsection

 

 

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1        (d) of Section 1-75 of this Act, as well as publicly
2        available analyses and studies performed by or for
3        regional transmission organizations that serve the
4        State and their independent market monitors.
5            Upon publishing of the zero emission standard
6        procurement plan, copies of the plan shall be posted
7        and made publicly available on the Agency's website.
8        All interested parties shall have 10 days following the
9        date of posting to provide comment to the Agency on the
10        plan. All comments shall be posted to the Agency's
11        website. Following the end of the comment period, but
12        no more than 60 days later than June 1, 2017 (the
13        effective date of Public Act 99-906) this amendatory
14        Act of the 99th General Assembly, the Agency shall
15        revise the plan as necessary based on the comments
16        received and file its zero emission standard
17        procurement plan with the Commission.
18            If the Commission determines that the plan will
19        result in the procurement of cost-effective zero
20        emission credits, then the Commission shall, after
21        notice and hearing, but no later than 45 days after the
22        Agency filed the plan, approve the plan or approve with
23        modification. For purposes of this subsection (d-5),
24        "cost effective" means the projected costs of
25        procuring zero emission credits from zero emission
26        facilities do not cause the limit stated in paragraph

 

 

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1        (2) of this subsection to be exceeded.
2            (C-5) As part of the Commission's review and
3        acceptance or rejection of the procurement results,
4        the Commission shall, in its public notice of
5        successful bidders:
6                (i) identify how the winning bids satisfy the
7            public interest criteria described in subparagraph
8            (C) of this paragraph (1) of minimizing carbon
9            dioxide emissions that result from electricity
10            consumed in Illinois and minimizing sulfur
11            dioxide, nitrogen oxide, and particulate matter
12            emissions that adversely affect the citizens of
13            this State;
14                (ii) specifically address how the selection of
15            winning bids takes into account the incremental
16            environmental benefits resulting from the
17            procurement, including any existing environmental
18            benefits that are preserved by the procurements
19            held under Public Act 99-906 this amendatory Act of
20            the 99th General Assembly and would have ceased to
21            exist if the procurements had not been held, such
22            as the preservation of zero emission facilities;
23                (iii) quantify the environmental benefit of
24            preserving the resources identified in item (ii)
25            of this subparagraph (C-5), including the
26            following:

 

 

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1                    (aa) the value of avoided greenhouse gas
2                emissions measured as the product of the zero
3                emission facilities' output over the contract
4                term multiplied by the U.S. Environmental
5                Protection Agency eGrid subregion carbon
6                dioxide emission rate and the U.S. Interagency
7                Working Group on Social Cost of Carbon's price
8                in the August 2016 Technical Update using a 3%
9                discount rate, adjusted for inflation for each
10                delivery year; and
11                    (bb) the costs of replacement with other
12                zero carbon dioxide resources, including wind
13                and photovoltaic, based upon the simple
14                average of the following:
15                        (I) the price, or if there is more than
16                    one price, the average of the prices, paid
17                    for renewable energy credits from new
18                    utility-scale wind projects in the
19                    procurement events specified in item (i)
20                    of subparagraph (G) of paragraph (1) of
21                    subsection (c) of Section 1-75 of this Act;
22                    and
23                        (II) the price, or if there is more
24                    than one price, the average of the prices,
25                    paid for renewable energy credits from new
26                    utility-scale solar projects and

 

 

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1                    brownfield site photovoltaic projects in
2                    the procurement events specified in item
3                    (ii) of subparagraph (G) of paragraph (1)
4                    of subsection (c) of Section 1-75 of this
5                    Act and, after January 1, 2015, renewable
6                    energy credits from photovoltaic
7                    distributed generation projects in
8                    procurement events held under subsection
9                    (c) of Section 1-75 of this Act.
10            Each utility shall enter into binding contractual
11        arrangements with the winning suppliers.
12            The procurement described in this subsection
13        (d-5), including, but not limited to, the execution of
14        all contracts procured, shall be completed no later
15        than May 10, 2017. Based on the effective date of
16        Public Act 99-906 this amendatory Act of the 99th
17        General Assembly, the Agency and Commission may, as
18        appropriate, modify the various dates and timelines
19        under this subparagraph and subparagraphs (C) and (D)
20        of this paragraph (1). The procurement and plan
21        approval processes required by this subsection (d-5)
22        shall be conducted in conjunction with the procurement
23        and plan approval processes required by subsection (c)
24        of this Section and Section 16-111.5 of the Public
25        Utilities Act, to the extent practicable.
26        Notwithstanding whether a procurement event is

 

 

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1        conducted under Section 16-111.5 of the Public
2        Utilities Act, the Agency shall immediately initiate a
3        procurement process on June 1, 2017 (the effective date
4        of Public Act 99-906) this amendatory Act of the 99th
5        General Assembly.
6            (D) Following the procurement event described in
7        this paragraph (1) and consistent with subparagraph
8        (B) of this paragraph (1), the Agency shall calculate
9        the payments to be made under each contract for the
10        next delivery year based on the market price index for
11        that delivery year. The Agency shall publish the
12        payment calculations no later than May 25, 2017 and
13        every May 25 thereafter.
14            (E) Notwithstanding the requirements of this
15        subsection (d-5), the contracts executed under this
16        subsection (d-5) shall provide that the zero emission
17        facility may, as applicable, suspend or terminate
18        performance under the contracts in the following
19        instances:
20                (i) A zero emission facility shall be excused
21            from its performance under the contract for any
22            cause beyond the control of the resource,
23            including, but not restricted to, acts of God,
24            flood, drought, earthquake, storm, fire,
25            lightning, epidemic, war, riot, civil disturbance
26            or disobedience, labor dispute, labor or material

 

 

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1            shortage, sabotage, acts of public enemy,
2            explosions, orders, regulations or restrictions
3            imposed by governmental, military, or lawfully
4            established civilian authorities, which, in any of
5            the foregoing cases, by exercise of commercially
6            reasonable efforts the zero emission facility
7            could not reasonably have been expected to avoid,
8            and which, by the exercise of commercially
9            reasonable efforts, it has been unable to
10            overcome. In such event, the zero emission
11            facility shall be excused from performance for the
12            duration of the event, including, but not limited
13            to, delivery of zero emission credits, and no
14            payment shall be due to the zero emission facility
15            during the duration of the event.
16                (ii) A zero emission facility shall be
17            permitted to terminate the contract if legislation
18            is enacted into law by the General Assembly that
19            imposes or authorizes a new tax, special
20            assessment, or fee on the generation of
21            electricity, the ownership or leasehold of a
22            generating unit, or the privilege or occupation of
23            such generation, ownership, or leasehold of
24            generation units by a zero emission facility.
25            However, the provisions of this item (ii) do not
26            apply to any generally applicable tax, special

 

 

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1            assessment or fee, or requirements imposed by
2            federal law.
3                (iii) A zero emission facility shall be
4            permitted to terminate the contract in the event
5            that the resource requires capital expenditures in
6            excess of $40,000,000 that were neither known nor
7            reasonably foreseeable at the time it executed the
8            contract and that a prudent owner or operator of
9            such resource would not undertake.
10                (iv) A zero emission facility shall be
11            permitted to terminate the contract in the event
12            the Nuclear Regulatory Commission terminates the
13            resource's license.
14            (F) If the zero emission facility elects to
15        terminate a contract under this subparagraph (E, of
16        this paragraph (1), then the Commission shall reopen
17        the docket in which the Commission approved the zero
18        emission standard procurement plan under subparagraph
19        (C) of this paragraph (1) and, after notice and
20        hearing, enter an order acknowledging the contract
21        termination election if such termination is consistent
22        with the provisions of this subsection (d-5).
23        (2) For purposes of this subsection (d-5), the amount
24    paid per kilowatthour means the total amount paid for
25    electric service expressed on a per kilowatthour basis. For
26    purposes of this subsection (d-5), the total amount paid

 

 

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1    for electric service includes, without limitation, amounts
2    paid for supply, transmission, distribution, surcharges,
3    and add-on taxes.
4        Notwithstanding the requirements of this subsection
5    (d-5), the contracts executed under this subsection (d-5)
6    shall provide that the total of zero emission credits
7    procured under a procurement plan shall be subject to the
8    limitations of this paragraph (2). For each delivery year,
9    the contractual volume receiving payments in such year
10    shall be reduced for all retail customers based on the
11    amount necessary to limit the net increase that delivery
12    year to the costs of those credits included in the amounts
13    paid by eligible retail customers in connection with
14    electric service to no more than 1.65% of the amount paid
15    per kilowatthour by eligible retail customers during the
16    year ending May 31, 2009. The result of this computation
17    shall apply to and reduce the procurement for all retail
18    customers, and all those customers shall pay the same
19    single, uniform cents per kilowatthour charge under
20    subsection (k) of Section 16-108 of the Public Utilities
21    Act. To arrive at a maximum dollar amount of zero emission
22    credits to be paid for the particular delivery year, the
23    resulting per kilowatthour amount shall be applied to the
24    actual amount of kilowatthours of electricity delivered by
25    the electric utility in the delivery year immediately prior
26    to the procurement, to all retail customers in its service

 

 

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1    territory. Unpaid contractual volume for any delivery year
2    shall be paid in any subsequent delivery year in which such
3    payments can be made without exceeding the amount specified
4    in this paragraph (2). The calculations required by this
5    paragraph (2) shall be made only once for each procurement
6    plan year. Once the determination as to the amount of zero
7    emission credits to be paid is made based on the
8    calculations set forth in this paragraph (2), no subsequent
9    rate impact determinations shall be made and no adjustments
10    to those contract amounts shall be allowed. All costs
11    incurred under those contracts and in implementing this
12    subsection (d-5) shall be recovered by the electric utility
13    as provided in this Section.
14        No later than June 30, 2019, the Commission shall
15    review the limitation on the amount of zero emission
16    credits procured under this subsection (d-5) and report to
17    the General Assembly its findings as to whether that
18    limitation unduly constrains the procurement of
19    cost-effective zero emission credits.
20        (3) Six years after the execution of a contract under
21    this subsection (d-5), the Agency shall determine whether
22    the actual zero emission credit payments received by the
23    supplier over the 6-year period exceed the Average ZEC
24    Payment. In addition, at the end of the term of a contract
25    executed under this subsection (d-5), or at the time, if
26    any, a zero emission facility's contract is terminated

 

 

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1    under subparagraph (E) of paragraph (1) of this subsection
2    (d-5), then the Agency shall determine whether the actual
3    zero emission credit payments received by the supplier over
4    the term of the contract exceed the Average ZEC Payment,
5    after taking into account any amounts previously credited
6    back to the utility under this paragraph (3). If the Agency
7    determines that the actual zero emission credit payments
8    received by the supplier over the relevant period exceed
9    the Average ZEC Payment, then the supplier shall credit the
10    difference back to the utility. The amount of the credit
11    shall be remitted to the applicable electric utility no
12    later than 120 days after the Agency's determination, which
13    the utility shall reflect as a credit on its retail
14    customer bills as soon as practicable; however, the credit
15    remitted to the utility shall not exceed the total amount
16    of payments received by the facility under its contract.
17        For purposes of this Section, the Average ZEC Payment
18    shall be calculated by multiplying the quantity of zero
19    emission credits delivered under the contract times the
20    average contract price. The average contract price shall be
21    determined by subtracting the amount calculated under
22    subparagraph (B) of this paragraph (3) from the amount
23    calculated under subparagraph (A) of this paragraph (3), as
24    follows:
25            (A) The average of the Social Cost of Carbon, as
26        defined in subparagraph (B) of paragraph (1) of this

 

 

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1        subsection (d-5), during the term of the contract.
2            (B) The average of the market price indices, as
3        defined in subparagraph (B) of paragraph (1) of this
4        subsection (d-5), during the term of the contract,
5        minus the baseline market price index, as defined in
6        subparagraph (B) of paragraph (1) of this subsection
7        (d-5).
8    If the subtraction yields a negative number, then the
9Average ZEC Payment shall be zero.
10        (4) Cost-effective zero emission credits procured from
11    zero emission facilities shall satisfy the applicable
12    definitions set forth in Section 1-10 of this Act.
13        (5) The electric utility shall retire all zero emission
14    credits used to comply with the requirements of this
15    subsection (d-5).
16        (6) Electric utilities shall be entitled to recover all
17    of the costs associated with the procurement of zero
18    emission credits through an automatic adjustment clause
19    tariff in accordance with subsection (k) and (m) of Section
20    16-108 of the Public Utilities Act, and the contracts
21    executed under this subsection (d-5) shall provide that the
22    utilities' payment obligations under such contracts shall
23    be reduced if an adjustment is required under subsection
24    (m) of Section 16-108 of the Public Utilities Act.
25        (7) This subsection (d-5) shall become inoperative on
26    January 1, 2028.

 

 

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1    (e) The draft procurement plans are subject to public
2comment, as required by Section 16-111.5 of the Public
3Utilities Act.
4    (f) The Agency shall submit the final procurement plan to
5the Commission. The Agency shall revise a procurement plan if
6the Commission determines that it does not meet the standards
7set forth in Section 16-111.5 of the Public Utilities Act.
8    (g) The Agency shall assess fees to each affected utility
9to recover the costs incurred in preparation of the annual
10procurement plan for the utility.
11    (h) The Agency shall assess fees to each bidder to recover
12the costs incurred in connection with a competitive procurement
13process.
14    (i) A renewable energy credit, carbon emission credit, or
15zero emission credit can only be used once to comply with a
16single portfolio or other standard as set forth in subsection
17(c), subsection (d), or subsection (d-5) of this Section,
18respectively. A renewable energy credit, carbon emission
19credit, or zero emission credit cannot be used to satisfy the
20requirements of more than one standard. If more than one type
21of credit is issued for the same megawatt hour of energy, only
22one credit can be used to satisfy the requirements of a single
23standard. After such use, the credit must be retired together
24with any other credits issued for the same megawatt hour of
25energy.
26(Source: P.A. 98-463, eff. 8-16-13; 99-536, eff. 7-8-16;

 

 

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199-906, eff. 6-1-17; revised 1-22-18.)
 
2    Section 15. The Public Utilities Act is amended by changing
3Sections 16-111.5 and 16-115A as follows:
 
4    (220 ILCS 5/16-111.5)
5    Sec. 16-111.5. Provisions relating to procurement.
6    (a) An electric utility that on December 31, 2005 served at
7least 100,000 customers in Illinois shall procure power and
8energy for its eligible retail customers in accordance with the
9applicable provisions set forth in Section 1-75 of the Illinois
10Power Agency Act and this Section; provided, that beginning
11with the delivery year commencing June 1, 2019, an electric
12utility that serves fewer than 3,000,000 retail customers, but
13more than 500,000 retail customers in Illinois shall procure
14capacity, including any demand response products, in
15accordance with subsection (b-5) of this Section. Beginning
16with the delivery year commencing on June 1, 2017, an such
17electric utility that on December 31, 2005 served at least
18100,000 customers in Illinois shall also procure zero emission
19credits from zero emission facilities in accordance with the
20applicable provisions set forth in Section 1-75 of the Illinois
21Power Agency Act, and, for years beginning on or after June 1,
222017, the utility shall procure renewable energy resources in
23accordance with the applicable provisions set forth in Section
241-75 of the Illinois Power Agency Act and this Section. A small

 

 

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1multi-jurisdictional electric utility that on December 31,
22005 served less than 100,000 customers in Illinois may elect
3to procure power and energy for all or a portion of its
4eligible Illinois retail customers in accordance with the
5applicable provisions set forth in this Section and Section
61-75 of the Illinois Power Agency Act. This Section shall not
7apply to a small multi-jurisdictional utility until such time
8as a small multi-jurisdictional utility requests the Illinois
9Power Agency to prepare a procurement plan for its eligible
10retail customers. "Eligible retail customers" for the purposes
11of this Section means those retail customers that purchase
12power and energy from the electric utility under fixed-price
13bundled service tariffs, other than those retail customers
14whose service is declared or deemed competitive under Section
1516-113 and those other customer groups specified in this
16Section, including self-generating customers, customers
17electing hourly pricing, or those customers who are otherwise
18ineligible for fixed-price bundled tariff service. For those
19customers that are excluded from the procurement plan's
20electric supply service requirements, and the utility shall
21procure any supply requirements, including capacity, ancillary
22services, and hourly priced energy, in the applicable markets
23as needed to serve those customers, provided that the utility
24may include in its procurement plan load requirements for the
25load that is associated with those retail customers whose
26service has been declared or deemed competitive pursuant to

 

 

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1Section 16-113 of this Act to the extent that those customers
2are purchasing power and energy during one of the transition
3periods identified in subsection (b) of Section 16-113 of this
4Act.
5    (b) Procurement plans A procurement plan shall be prepared
6for each electric utility consistent with the applicable
7requirements of the Illinois Power Agency Act and this Section.
8For purposes of this Section, Illinois electric utilities that
9are affiliated by virtue of a common parent company are
10considered to be a single electric utility. Small
11multi-jurisdictional utilities may request a procurement plan
12for a portion of or all of its Illinois load. Each procurement
13plan shall analyze the projected balance of supply and demand
14for those retail customers to be included in the plan's
15electric supply service requirements over a 5-year period, with
16the first planning year beginning on June 1 of the year
17following the year in which the plan is filed. The plan shall
18specifically identify the wholesale products to be procured
19following plan approval, and shall follow all the requirements
20set forth in the Public Utilities Act and all applicable State
21and federal laws, statutes, rules, or regulations, as well as
22Commission orders. Nothing in this Section precludes
23consideration of contracts longer than 5 years and related
24forecast data. Unless specified otherwise in this Section, in
25the procurement plan or in the implementing tariff, any
26procurement occurring in accordance with this plan shall be

 

 

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1competitively bid through a request for proposals process.
2Approval and implementation of the procurement plan shall be
3subject to review and approval by the Commission according to
4the provisions set forth in this Section. A procurement plan
5shall include each of the following components:
6        (1) Hourly load analysis. This analysis shall include:
7            (i) multi-year historical analysis of hourly
8        loads;
9            (ii) switching trends and competitive retail
10        market analysis;
11            (iii) known or projected changes to future loads;
12        and
13            (iv) growth forecasts by customer class.
14        (2) Analysis of the impact of any demand side and
15    renewable energy initiatives. This analysis shall include:
16            (i) the impact of demand response programs and
17        energy efficiency programs, both current and
18        projected; for small multi-jurisdictional utilities,
19        the impact of demand response and energy efficiency
20        programs approved pursuant to Section 8-408 of this
21        Act, both current and projected; and
22            (ii) supply side needs that are projected to be
23        offset by purchases of renewable energy resources, if
24        any.
25        (3) A plan for meeting the expected load requirements
26    that will not be met through preexisting contracts. This

 

 

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1    plan shall include:
2            (i) definitions of the different Illinois retail
3        customer classes for which supply is being purchased;
4            (ii) the proposed mix of demand-response products
5        for which contracts will be executed during the next
6        year. For small multi-jurisdictional electric
7        utilities that on December 31, 2005 served fewer than
8        100,000 customers in Illinois, these shall be defined
9        as demand-response products offered in an energy
10        efficiency plan approved pursuant to Section 8-408 of
11        this Act. The cost-effective demand-response measures
12        shall be procured whenever the cost is lower than
13        procuring comparable capacity products, provided that
14        such products shall:
15                (A) be procured by a demand-response provider
16            from those retail customers included in the plan's
17            electric supply service requirements;
18                (B) at least satisfy the demand-response
19            requirements of the regional transmission
20            organization market in which the utility's service
21            territory is located, including, but not limited
22            to, any applicable capacity or dispatch
23            requirements;
24                (C) provide for customers' participation in
25            the stream of benefits produced by the
26            demand-response products;

 

 

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1                (D) provide for reimbursement by the
2            demand-response provider of the utility for any
3            costs incurred as a result of the failure of the
4            supplier of such products to perform its
5            obligations thereunder; and
6                (E) meet the same credit requirements as apply
7            to suppliers of capacity, in the applicable
8            regional transmission organization market;
9            (iii) monthly forecasted system supply
10        requirements, including expected minimum, maximum, and
11        average values for the planning period;
12            (iv) the proposed mix and selection of standard
13        wholesale products for which contracts will be
14        executed during the next year, separately or in
15        combination, to meet that portion of its load
16        requirements not met through pre-existing contracts,
17        including but not limited to monthly 5 x 16 peak period
18        block energy, monthly off-peak wrap energy, monthly 7 x
19        24 energy, annual 5 x 16 energy, annual off-peak wrap
20        energy, annual 7 x 24 energy, monthly capacity, annual
21        capacity, peak load capacity obligations, capacity
22        purchase plan, and ancillary services;
23            (v) proposed term structures for each wholesale
24        product type included in the proposed procurement plan
25        portfolio of products; and
26            (vi) an assessment of the price risk, load

 

 

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1        uncertainty, and other factors that are associated
2        with the proposed procurement plan; this assessment,
3        to the extent possible, shall include an analysis of
4        the following factors: contract terms, time frames for
5        securing products or services, fuel costs, weather
6        patterns, transmission costs, market conditions, and
7        the governmental regulatory environment; the proposed
8        procurement plan shall also identify alternatives for
9        those portfolio measures that are identified as having
10        significant price risk.
11        (4) Proposed procedures for balancing loads. The
12    procurement plan shall include, for load requirements
13    included in the procurement plan, the process for (i)
14    hourly balancing of supply and demand and (ii) the criteria
15    for portfolio re-balancing in the event of significant
16    shifts in load.
17        (5) Long-Term Renewable Resources Procurement Plan.
18    The Agency shall prepare a long-term renewable resources
19    procurement plan for the procurement of renewable energy
20    credits under Sections 1-56 and 1-75 of the Illinois Power
21    Agency Act for delivery beginning in the 2017 delivery
22    year.
23            (i) The initial long-term renewable resources
24        procurement plan and all subsequent revisions shall be
25        subject to review and approval by the Commission. For
26        the purposes of this Section, "delivery year" has the

 

 

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1        same meaning as in Section 1-10 of the Illinois Power
2        Agency Act. For purposes of this Section, "Agency"
3        shall mean the Illinois Power Agency.
4            (ii) The long-term renewable resources planning
5        process shall be conducted as follows:
6                (A) Electric utilities shall provide a range
7            of load forecasts to the Illinois Power Agency
8            within 45 days of the Agency's request for
9            forecasts, which request shall specify the length
10            and conditions for the forecasts including, but
11            not limited to, the quantity of distributed
12            generation expected to be interconnected for each
13            year.
14                (B) The Agency shall publish for comment the
15            initial long-term renewable resources procurement
16            plan no later than 120 days after the effective
17            date of this amendatory Act of the 99th General
18            Assembly and shall review, and may revise, the plan
19            at least every 2 years thereafter. To the extent
20            practicable, the Agency shall review and propose
21            any revisions to the long-term renewable energy
22            resources procurement plan in conjunction with the
23            Agency's other planning and approval processes
24            conducted under this Section. The initial
25            long-term renewable resources procurement plan
26            shall:

 

 

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1                    (aa) Identify the procurement programs and
2                competitive procurement events consistent with
3                the applicable requirements of the Illinois
4                Power Agency Act and shall be designed to
5                achieve the goals set forth in subsection (c)
6                of Section 1-75 of that Act.
7                    (bb) Include a schedule for procurements
8                for renewable energy credits from
9                utility-scale wind projects, utility-scale
10                solar projects, and brownfield site
11                photovoltaic projects consistent with
12                subparagraph (G) of paragraph (1) of
13                subsection (c) of Section 1-75 of the Illinois
14                Power Agency Act.
15                    (cc) Identify the process whereby the
16                Agency will submit to the Commission for review
17                and approval the proposed contracts to
18                implement the programs required by such plan.
19                Copies of the initial long-term renewable
20            resources procurement plan and all subsequent
21            revisions shall be posted and made publicly
22            available on the Agency's and Commission's
23            websites, and copies shall also be provided to each
24            affected electric utility. An affected utility and
25            other interested parties shall have 45 days
26            following the date of posting to provide comment to

 

 

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1            the Agency on the initial long-term renewable
2            resources procurement plan and all subsequent
3            revisions. All comments submitted to the Agency
4            shall be specific, supported by data or other
5            detailed analyses, and, if objecting to all or a
6            portion of the procurement plan, accompanied by
7            specific alternative wording or proposals. All
8            comments shall be posted on the Agency's and
9            Commission's websites. During this 45-day comment
10            period, the Agency shall hold at least one public
11            hearing within each utility's service area that is
12            subject to the requirements of this paragraph (5)
13            for the purpose of receiving public comment.
14            Within 21 days following the end of the 45-day
15            review period, the Agency may revise the long-term
16            renewable resources procurement plan based on the
17            comments received and shall file the plan with the
18            Commission for review and approval.
19                (C) Within 14 days after the filing of the
20            initial long-term renewable resources procurement
21            plan or any subsequent revisions, any person
22            objecting to the plan may file an objection with
23            the Commission. Within 21 days after the filing of
24            the plan, the Commission shall determine whether a
25            hearing is necessary. The Commission shall enter
26            its order confirming or modifying the initial

 

 

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1            long-term renewable resources procurement plan or
2            any subsequent revisions within 120 days after the
3            filing of the plan by the Illinois Power Agency.
4                (D) The Commission shall approve the initial
5            long-term renewable resources procurement plan and
6            any subsequent revisions, including expressly the
7            forecast used in the plan and taking into account
8            that funding will be limited to the amount of
9            revenues actually collected by the utilities, if
10            the Commission determines that the plan will
11            reasonably and prudently accomplish the
12            requirements of Section 1-56 and subsection (c) of
13            Section 1-75 of the Illinois Power Agency Act. The
14            Commission shall also approve the process for the
15            submission, review, and approval of the proposed
16            contracts to procure renewable energy credits or
17            implement the programs authorized by the
18            Commission pursuant to a long-term renewable
19            resources procurement plan approved under this
20            Section.
21            (iii) The Agency or third parties contracted by the
22        Agency shall implement all programs authorized by the
23        Commission in an approved long-term renewable
24        resources procurement plan without further review and
25        approval by the Commission. Third parties shall not
26        begin implementing any programs or receive any payment

 

 

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1        under this Section until the Commission has approved
2        the contract or contracts under the process authorized
3        by the Commission in item (D) of subparagraph (ii) of
4        paragraph (5) of this subsection (b) and the third
5        party and the Agency or utility, as applicable, have
6        executed the contract. For those renewable energy
7        credits subject to procurement through a competitive
8        bid process under the plan or under the initial forward
9        procurements for wind and solar resources described in
10        subparagraph (G) of paragraph (1) of subsection (c) of
11        Section 1-75 of the Illinois Power Agency Act, the
12        Agency shall follow the procurement process specified
13        in the provisions relating to electricity procurement
14        in subsections (e) through (i) of this Section.
15            (iv) An electric utility shall recover its costs
16        associated with the procurement of renewable energy
17        credits under this Section through an automatic
18        adjustment clause tariff under subsection (k) of
19        Section 16-108 of this Act. A utility shall not be
20        required to advance any payment or pay any amounts
21        under this Section that exceed the actual amount of
22        revenues collected by the utility under paragraph (6)
23        of subsection (c) of Section 1-75 of the Illinois Power
24        Agency Act and subsection (k) of Section 16-108 of this
25        Act, and contracts executed under this Section shall
26        expressly incorporate this limitation.

 

 

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1            (v) For the public interest, safety, and welfare,
2        the Agency and the Commission may adopt rules to carry
3        out the provisions of this Section on an emergency
4        basis immediately following the effective date of this
5        amendatory Act of the 99th General Assembly.
6            (vi) On or before July 1 of each year, the
7        Commission shall hold an informal hearing for the
8        purpose of receiving comments on the prior year's
9        procurement process and any recommendations for
10        change.
11    (b-5)(1) For purposes of this Section:
12        "Midcontinent Independent System Operator" shall mean
13    the Midcontinent Independent System Operator, Inc., or its
14    successor approved by the Federal Energy Regulatory
15    Commission as the regional transmission organization for
16    the Applicable Local Resource Zone.
17        "MISO Tariff" shall mean the open access transmission
18    and energy markets tariff of the Midcontinent Independent
19    System Operator, Inc. or its successor, as that tariff may
20    be updated from time to time.
21        "Fixed Resource Adequacy Plan", "Load Serving Entity",
22    "Local Clearing Requirement", "Local Resource Zone",
23    "Planning Resource", and "Planning Reserve Margin
24    Requirement" shall have the meanings set forth in the MISO
25    Tariff.
26        "Peak Load Contribution" shall mean the peak load

 

 

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1    contribution, calculated in the manner specified in the
2    MISO Tariff, of, as applicable, a retail customer, a group
3    of retail customers served by a Load Serving Entity, or all
4    retail customers of the Applicable Electric Utility in the
5    Applicable Local Resource Zone.
6        "Applicable Electric Utility" shall mean an electric
7    utility serving less than 3,000,000 retail customers and
8    more than 500,000 retail customers in this State.
9        "Applicable Local Resource Zone" shall have the
10    meaning set forth in Section 1-75 of the Illinois Power
11    Agency Act.
12        "Municipal utility" shall mean an entity described in
13    paragraph (1) of subsection (b) of Section 3-105 of this
14    Act.
15        "Electric cooperative" shall have the meaning set
16    forth in Section 3-119 of this Act.
17        "Contracted LSE Capacity" shall mean the amount of
18    capacity that a Load Serving Entity (i) has procured and
19    has under contract for the delivery year beginning June 1,
20    2019 or June 1, 2020 under a contract or contracts entered
21    into no later than the effective date of this amendatory
22    Act of the 100th General Assembly, for purposes of serving
23    retail customers of the Applicable Electric Utility in the
24    Applicable Local Resource Zone; and (ii) certifies to the
25    Agency, in a certification signed by an officer of the Load
26    Serving Entity and submitted to the Agency no later than 30

 

 

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1    days following the effective date of this amendatory Act of
2    the 100th General Assembly, that the Load Serving Entity
3    has procured and has under contract. For purposes of this
4    definition, capacity under contract shall include capacity
5    that a supplier of capacity has entered into a written
6    commitment to provide to a Load Serving Entity that is a
7    corporate affiliate of the capacity supplier.
8        (2)(A) During the period between January 1 and March 1
9    of 2019, and of each year thereafter, the Agency, and, as
10    applicable, the procurement administrator, shall conduct a
11    capacity procurement event to procure capacity that is
12    sufficient, together with capacity procured in previous
13    capacity procurement events, to meet at least 90% of the
14    portion of the projected Planning Reserve Margin
15    Requirement for the delivery year beginning the third June
16    1 following the capacity procurement event that is
17    attributable to the projected load of the retail customers
18    of each Applicable Electric Utility. Provided, that (i) the
19    initial capacity procurement event conducted in 2019 shall
20    also procure capacity that is sufficient to meet at least
21    90% of the projected Planning Reserve Margin Requirement
22    for the delivery years beginning June 1, 2020 that is
23    attributable to the projected load of the retail customers
24    of each Applicable Electric Utility; and (ii) each capacity
25    procurement event shall also procure any additional
26    capacity that is necessary, together with capacity

 

 

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1    procured in previous annual capacity procurement events,
2    to meet 100% of the portion of the Planning Reserve Margin
3    Requirement for the delivery year beginning June 1 of that
4    same year that is attributable to the projected load of the
5    retail customers of each Applicable Electric Utility. The
6    capacity procurement plans developed by the Agency and the
7    capacity procurement events shall be designed to procure
8    capacity to ensure long-term resource adequacy at the
9    lowest cost over time, taking into account the benefits of
10    price stability and the need to ensure the reliability,
11    adequacy, and resilience of the bulk power generation and
12    delivery system in the Applicable Local Resource Zone.
13            (B) In determining or projecting the Planning
14        Reserve Margin Requirement and the Local Clearing
15        Requirement in the Applicable Local Resource Zone
16        attributable to the retail customers of the Applicable
17        Electric Utility for a delivery year for purposes of
18        capacity procurement plans and capacity procurement
19        events under this subsection (b-5), the Agency and, as
20        applicable, the procurement administrator shall use,
21        as applicable, the Planning Reserve Margin
22        Requirement, Peak Load Contribution, and Local
23        Clearing Requirement as established or projected by
24        the Midcontinent Independent System Operator. If the
25        Midcontinent Independent System Operator has not
26        established or released a projection of the Planning

 

 

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1        Reserve Margin Requirement, Peak Load Contribution, or
2        Local Clearing Requirement for a delivery year, the
3        Agency and, as applicable, the procurement
4        administrator shall develop forecasts of the Planning
5        Reserve Margin Requirement, Peak Load Contribution,
6        and Local Clearing Requirement for that delivery year
7        based on available information, including, without
8        limiting the foregoing, the most recent Planning
9        Reserve Margin Requirement, Peak Load Contribution,
10        and Local Clearing Requirement established by the
11        Midcontinent Independent System Operator for a
12        delivery year and any other information from the
13        Midcontinent Independent System Operator and the
14        Applicable Electric Utility. If requested by the
15        Agency, the Applicable Electric Utility shall provide
16        to the Agency actual and forecasted peak electric load
17        information for the retail customers of the Applicable
18        Electric Utility in the Applicable Local Resource
19        Zone.
20        (3)(A) Each capacity procurement event may include the
21    procurement of capacity through a mix of contracts with
22    different terms and different initial delivery dates as
23    proposed by the Agency in its capacity procurement plan and
24    approved by the Commission, so long as each annual capacity
25    procurement event results in the procurement of an amount
26    of capacity that, together with capacity procured in

 

 

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1    previous capacity procurement events, is equal to the
2    portion or portions of the projected Planning Reserve
3    Margin Requirement of the retail customers of each
4    Applicable Electric Utility for the delivery year or
5    delivery years for which capacity is to be procured as
6    specified in paragraph (2) of this subsection (b-5).
7    Provided, that in the initial procurement event conducted
8    in 2019, a portion, as proposed by the Agency and approved
9    by the Commission, of the capacity shall be procured under
10    contracts with a term of at least 3 years beginning June 1,
11    2019.
12            (B) The Agency's annual capacity procurement plans
13        for the Applicable Local Resource Zone shall be
14        developed as follows: No later than July 15 of each
15        year, the Agency shall post on its website and
16        otherwise make publicly available, for public comment,
17        its draft capacity procurement plan for the capacity
18        procurement event to be held in February of the
19        following calendar year. Interested parties shall be
20        allowed 30 days from the posting of the draft capacity
21        procurement plan to submit comments to the Agency. The
22        Agency shall consider any comments received and shall
23        file its proposed capacity procurement plan with the
24        Commission within 15 days following the conclusion of
25        the public comment period. The Commission shall open a
26        docketed proceeding for consideration and approval or

 

 

HB5134- 111 -LRB100 20041 SMS 35323 b

1        modification of the proposed capacity procurement
2        plan. The Commission or its administrative law judge
3        assigned to the proceeding shall establish a
4        procedural schedule for the proceeding that will
5        enable the Commission to issue an order, within 90 days
6        following the date the capacity procurement plan was
7        filed with the Commission, approving, with any
8        modifications directed by the Commission, the capacity
9        procurement plan. On or before December 1 each year,
10        the Commission shall issue its order in the proceeding
11        approving, or approving with modifications, the
12        capacity procurement plan.
13        (4) To the extent that any other provision of this
14    Section or any provision of the Illinois Power Agency Act
15    are not inconsistent with the provisions of this subsection
16    (b-5) for, and are otherwise applicable to, capacity
17    procurement events conducted under this subsection (b-5),
18    those other provisions shall be used in conducting capacity
19    procurement events conducted under this subsection (b-5).
20        (5) The capacity procurement plans prepared by, and the
21    capacity procurement events conducted by, the Agency under
22    this subsection (b-5) shall be subject to the following
23    requirements:
24            (A) The mix of capacity resources selected in any
25        procurement event conducted under this subsection
26        (b-5) must include sufficient qualified Zonal Resource

 

 

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1        Credits, together with capacity procured in previous
2        capacity procurement events, to satisfy the portion
3        specified in paragraph (2) of this subsection (b-5) of
4        the Planning Reserve Margin Requirements of the MISO
5        Tariff for the Applicable Local Resource Zone, and must
6        otherwise be consistent with the Planning Reserve
7        Margin Requirements for capacity established by the
8        Midcontinent Independent System Operator. Provided,
9        that the procurement of capacity in the capacity
10        procurement events shall not include the portion of the
11        Planning Reserve Margin Requirement for the Applicable
12        Local Resource Zone associated with customers served
13        by a municipal utility or an electric cooperative.
14            (B) The capacity to be procured for each delivery
15        year shall include an amount of capacity from capacity
16        resources physically located within the Applicable
17        Local Resource Zone that is no less than the portion of
18        the projected Local Clearing Requirement for the
19        Applicable Local Resource Zone for that delivery year
20        attributable to the load of the retail customers of the
21        Applicable Electric Utility.
22            (C) In each capacity procurement plan, the Agency
23        shall include a discussion of whether factors, other
24        than price, to support reliability in the Applicable
25        Local Resource Zone should be taken into account in
26        selecting capacity resources in the capacity

 

 

HB5134- 113 -LRB100 20041 SMS 35323 b

1        procurement event or events that are the subject of the
2        capacity procurement plan. The Agency may propose in
3        the capacity procurement plan to procure a specified
4        amount or amounts of capacity from capacity resources
5        located within the Applicable Local Resource Zone,
6        over and above the amount of capacity required to
7        satisfy the Local Clearing Requirement, to support
8        reliability within the Applicable Local Resource Zone,
9        including, but not limited to, for purposes of
10        transmission security, voltage support, dynamic
11        stability, frequency response, fuel security and
12        on-site fuel supply, and import transfer capability.
13        The inclusion of any such factors in the capacity
14        procurement plan shall be subject to approval of the
15        Commission.
16            (D) Any capacity resource, including, without
17        limitation, demand response resources, energy
18        efficiency resources, and renewable energy resources,
19        that meets the other eligibility requirements of this
20        subsection (b-5), shall be eligible to participate in a
21        capacity procurement event under this subsection (b-5)
22        if, and to the extent that, the resource satisfies all
23        the requirements of the MISO Tariff to be designated as
24        a Zonal Resource Credit or other Planning Resource in a
25        Load Serving Entity's Fixed Resource Adequacy Plan or
26        successor mechanism for the Applicable Local Resource

 

 

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1        Zone. Provided, that a municipal utility, an electric
2        cooperative, a municipal electric power agency or
3        other group, association, or consortium of municipal
4        utilities or electric cooperatives may participate in
5        a capacity procurement event, using capacity that it
6        owns or leases, only to the extent that the owned and
7        leased capacity of the municipal utility, electric
8        cooperative, municipal electric power agency, or
9        group, association, or consortium exceeds the Planning
10        Reserve Margin Requirement (or comparable measure in
11        the regional transmission organization in which the
12        customers of the municipal utility, electric
13        cooperative, municipal electric power agency, or
14        members of the group, association, or consortium are
15        located) attributable to the load of the customers that
16        the municipal utility, electric cooperative, municipal
17        electric power agency, or group, association, or
18        consortium is obligated to serve. As a condition to
19        eligibility to participate in a capacity procurement
20        event conducted under this subsection (b-5), each
21        municipal utility, electric cooperative, municipal
22        electric power agency, and group, association, and
23        consortium of municipal utilities or electric
24        cooperatives shall certify its compliance with this
25        requirement to the Agency for the capacity procurement
26        event.

 

 

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1            (E) As a condition to eligibility to participate in
2        a capacity procurement event conducted under this
3        subsection (b-5), a supplier of capacity resources (i)
4        must commit to pay any fees assessed by the Agency to
5        recover the Agency's costs of conducting the capacity
6        procurement event and any related activities under
7        this subsection (b-5); (ii) must agree that, if
8        selected as a supplier in the capacity procurement
9        event, it will enter into a standard form contract
10        developed by the procurement administrator and
11        conforming to the requirements of this subsection
12        (b-5) with each Load Serving Entity for which capacity
13        is procured in the capacity procurement event; and
14        (iii) must agree and commit that if selected as a
15        supplier in the capacity procurement event, it will
16        operate the selected capacity resource from the date of
17        execution of the contract through the end of the
18        contract term, subject to occurrence of force majeure
19        events and other grounds for suspension or termination
20        of operation of the capacity resource or termination of
21        the contract in accordance with the terms of the
22        contract as specified in subparagraph (F) of paragraph
23        (9) of this subsection (b-5).
24            (F) For each capacity procurement event conducted
25        under this subsection (b-5), the procurement
26        administrator, in consultation with the Commission

 

 

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1        staff, Agency staff, and the procurement monitor,
2        shall establish confidential market-based benchmarks,
3        in accordance with paragraph (3) of subsection (e) of
4        this Section, for evaluating the final prices in the
5        contracts for the capacity that will be procured.
6            (G) In each capacity procurement event conducted
7        under this subsection (b-5), the procurement
8        administrator shall select capacity resources in the
9        amounts offered by capacity suppliers based on each
10        capacity supplier's offer price until sufficient
11        capacity (including any capacity offered under item
12        (ii) of subparagraph (H) and subparagraph (J) of this
13        paragraph (5) of this subsection (b-5)) has been
14        selected to reach the total amount of capacity to be
15        selected for each delivery year for which capacity is
16        being procured in the capacity procurement event.
17        Provided, that in selecting capacity resources, the
18        procurement administrator shall also take into
19        account, in accordance with and to the extent and in
20        the manner specified in, the capacity procurement plan
21        approved by the Commission for the capacity
22        procurement event, other factors to support
23        reliability in the Applicable Local Resource Zone,
24        including, but not limited to, for purposes of
25        transmission security, voltage support, dynamic
26        stability, frequency response, fuel security and

 

 

HB5134- 117 -LRB100 20041 SMS 35323 b

1        on-site fuel supply, and import transfer capability.
2            If the procurement administrator, or the
3        Commission upon receiving the procurement
4        administrator's recommendation submitted under item
5        (ix) of paragraph (1) of subsection (c) of this Section
6        for the immediately upcoming delivery year beginning
7        on the immediately upcoming June 1, determines that an
8        insufficient amount of capacity has been offered in
9        bids that conform to the bidding requirements for the
10        capacity procurement event and at bid prices that are
11        deemed reasonable as compared to the applicable
12        benchmarks to fulfill the capacity procurement
13        objectives of the capacity procurement event, then the
14        Agency and the procurement administrator, in their
15        discretion, shall either (i) if sufficient time
16        remains prior to March 1, expeditiously conduct an
17        additional bid solicitation to procure additional
18        capacity for the immediately upcoming delivery year;
19        or (ii) notify the Load Serving Entities in the
20        Applicable Local Resource Zone that any additional
21        capacity required to meet the Planning Reserve Margin
22        Requirement obligations of the Load Serving Entity for
23        the immediately upcoming delivery year shall be
24        obtained through the planning reserve auction or other
25        auction conducted by the Midcontinent Independent
26        System Operator.

 

 

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1            (H) For the initial capacity procurement event to
2        be conducted in 2019 to procure capacity for the
3        delivery years beginning June 1, 2019, June 1, 2020,
4        and June 1, 2021, any Load Serving Entity holding
5        Contracted LSE Capacity may, but shall not be required
6        to, participate in the capacity procurement event as a
7        supplier of capacity resources using either of the
8        following two options:
9                (i) The Load Serving Entity may bid all or a
10            portion of its Contracted LSE Capacity into the
11            capacity procurement event as a capacity resource,
12            at a specified offer price, and the Contracted LSE
13            Capacity bid shall be eligible to be selected by
14            the procurement administrator in accordance with
15            subparagraph (G) of this paragraph (5) of this
16            subsection (b-5).
17                (ii) The Load Serving Entity may designate all
18            or a portion of its Contracted LSE Capacity to be
19            selected by the procurement administrator at a
20            price equal to the weighted average offer price of
21            all other capacity resources selected by the
22            procurement administrator. Under this option, the
23            Load Serving Entity's Contracted LSE Capacity is
24            selected as a capacity resource at a price equal to
25            the weighted average offer price of all other
26            capacity resources selected by the procurement

 

 

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1            administrator.
2            Under either items (i) or (ii), the Contracted LSE
3        Capacity must be supplied from a capacity resource that
4        meets the other requirements of this subsection (b-5)
5        to participate and be selected in the capacity
6        procurement event, and the Contracted LSE Capacity
7        must be offered for a contract term lasting until the
8        end date of the Load Serving Entity's contract term for
9        the Contracted LSE Capacity or until May 31, 2021,
10        whichever occurs earlier. A Load Serving Entity shall
11        not be required to use either of the options specified
12        in this subparagraph (H) for its Contracted LSE
13        Capacity. The Agency shall maintain as confidential
14        and proprietary and exempt from disclosure the amount
15        of Contracted LSE Capacity certified by a Load Serving
16        Entity to the Agency, except to the extent that the
17        Load-Serving Entity elects to use one or both of the
18        options specified in this subparagraph (H).
19            (I) Each capacity supplier whose capacity resource
20        is selected shall enter into contracts conforming to
21        the provisions of this subsection (b-5) with the Load
22        Serving Entities serving the retail customers of the
23        Applicable Electric Utility in the Applicable Local
24        Resource Zone for, in the aggregate, the total amount
25        of capacity selected at the price bid by the capacity
26        supplier for that amount of capacity. Provided, that

 

 

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1        (i) the procurement administrator shall have authority
2        to negotiate with a capacity supplier that submitted a
3        bid price below the applicable benchmark price
4        established for the capacity procurement event to
5        lower that capacity supplier's bid price, as provided
6        in item (vii) of subparagraph (1) of subsection (c) of
7        this Section; and (ii) the selection of capacity
8        suppliers, the amounts of capacity selected from each
9        supplier, and the prices for any capacity resources
10        selected in a capacity procurement event shall be
11        subject to the approval of the Commission in accordance
12        with subsection (f) of this Section.
13            (J) Capacity awarded in the Peak Time Rewards
14        program or successor program, if any, of an Applicable
15        Electric Utility shall be included in the capacity
16        resources selected for each delivery year for which
17        capacity is procured in a capacity procurement event,
18        at a price for that delivery year equal to the weighted
19        average price of the other capacity resources selected
20        under this subsection (b-5) for the delivery year.
21        Prior to a capacity procurement event being conducted
22        under this subsection (b-5) to procure capacity for a
23        delivery year, the Applicable Electric Utility shall
24        notify the Agency and the procurement administrator of
25        the amount of capacity awarded or forecasted to be
26        awarded in the Peak Time Rewards program for each

 

 

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1        delivery year for which capacity is to be procured in
2        the capacity procurement event. For purposes of
3        contract administration and settlements, the
4        Applicable Electric Utility shall be deemed the
5        capacity supplier of capacity awarded in its Peak Time
6        Rewards program or successor program.
7        (6) Each (i) capacity supplier selected in a capacity
8    procurement event conducted by the Illinois Power Agency
9    under this subsection (b-5), including each Load Serving
10    Entity offering Contracted LSE Capacity under item (i) of
11    subparagraph (H) of paragraph (5) of this subsection (b-5)
12    that is selected in the capacity procurement event, each
13    Load Serving Entity designating Contracted LSE Capacity
14    under item (ii) of subparagraph (H) of paragraph (5) of
15    this subsection (b-5), and an Applicable Electric Utility
16    as the supplier of capacity awarded under its Peak Time
17    Rewards program or successor program in accordance with
18    subparagraph (J) of paragraph (5) of this subsection (b-5);
19    and (ii) each Load Serving Entity serving retail customers
20    of an Applicable Electric Utility in an Applicable Resource
21    Zone, shall enter into contracts for capacity developed by
22    the procurement administrator in accordance with paragraph
23    (9) of this subsection (b-5).
24        (7) The Agency shall request that the Midcontinent
25    Independent System Operator serve as and perform the
26    responsibilities of the capacity data administrator as set

 

 

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1    forth in this subsection (b-5). If the Midcontinent
2    Independent System Operator declines to serve as, or
3    resigns as, the capacity data administrator, the Agency,
4    after consultation with the Commission, shall contract
5    with a third party to serve as the capacity data
6    administrator. The costs of the capacity data
7    administrator to perform its responsibilities under this
8    subsection (b-5) shall be reimbursed by the Agency. The
9    Agency shall recover such costs through fees assessed to
10    the Load Serving Entities that enter into contracts for
11    capacity under this Section.
12        (8) The Applicable Electric Utility shall supply to the
13    capacity data administrator, on a daily basis, a report or
14    reports showing the total load of the Applicable Electric
15    Utility's retail customers in the Applicable Local
16    Resource Zone that is served by each Load Serving Entity on
17    each day. Based upon and in reliance on the information
18    provided by the Applicable Electric Utility, the capacity
19    data administrator shall issue daily reports to each
20    capacity supplier and each Load Serving Entity setting
21    forth the amount of capacity being provided by each
22    capacity supplier under its contract with each Load Serving
23    Entity on that day, calculated in accordance with
24    subparagraph (C) of paragraph (9) of this subsection (b-5).
25        (9) The procurement administrator, in conjunction with
26    the Agency and the staff of the Commission and based on

 

 

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1    consultation with prospective capacity suppliers and with
2    Load Serving Entities serving retail customers of
3    Applicable Electric Utilities in an Applicable Local
4    Resource Zone, shall promulgate, and shall revise from time
5    to time as necessary and appropriate, standard form
6    contracts to be entered into between the Load Serving
7    Entities and capacity suppliers selected in procurement
8    events conducted under this subsection (b-5). The standard
9    form contracts to be used in connection with each capacity
10    procurement event conducted under this subsection (b-5)
11    shall be made available to prospective capacity suppliers
12    prior to the capacity procurement event. Each capacity
13    supplier seeking to participate in a capacity procurement
14    event shall agree, as a condition of eligibility to
15    participate, that if selected, it will enter into the
16    standard form contract with each Load Serving Entity
17    serving retail customers of the Applicable Electric
18    Utility in the Applicable Local Resource Zone. The standard
19    form contracts shall contain, without limitation, the
20    following provisions.
21            (A) Each contract between a capacity supplier and a
22        Load Serving Entity shall specify that the amount of
23        capacity to be provided by the capacity supplier and
24        purchased by the Load Serving Entity shall be that
25        portion of the total capacity to be supplied by the
26        capacity supplier equal to the load ratio share of the

 

 

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1        Applicable Electric Utility's retail customers served
2        by the Load Serving Entity as a percentage of the total
3        Planning Reserve Margin Requirement attributable to
4        the load of the Applicable Electric Utility's retail
5        customers in the Applicable Local Resource Zone on
6        March 1 immediately preceding the first delivery year
7        for which the contract is in effect.
8            (B) The standard form contracts shall specify that
9        if the Agency determines between March 1 and June 1 of
10        a year that the aggregate amount of capacity procured
11        in capacity procurement events for the immediately
12        upcoming delivery year beginning June 1 exceeds the
13        amount of capacity needed to meet the Planning Reserve
14        Margin Requirement attributable to the load of the
15        retail customers of the Applicable Electric Utility in
16        the Applicable Local Resource Zone, and directs that
17        the capacity to be supplied by each capacity supplier
18        for the immediately upcoming delivery year beginning
19        June 1 shall be reduced on a pro rata basis so that the
20        aggregate amount of capacity to be supplied for the
21        immediately upcoming delivery year is equal to the
22        amount of capacity needed to meet the Planning Reserve
23        Margin Requirement attributable to the load of the
24        retail customers of the Applicable Electric Utility in
25        the Applicable Local Resource Zone, then the amount of
26        capacity to be supplied and purchased under each

 

 

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1        contract between a capacity supplier and a Load Serving
2        Entity shall be deemed reduced as directed by the
3        Agency. The standard form contract shall specify that
4        any such reduction in the capacity to be supplied under
5        the contract shall apply only to the immediately
6        upcoming delivery year and not to any subsequent years
7        in the contract term. The standard form contracts shall
8        provide that in the event of a reduction in the
9        capacity to be supplied in accordance with this
10        subparagraph (B), the capacity supplier may resell or
11        otherwise dispose of the capacity it is no longer
12        obligated to supply, including by offering the
13        capacity into a planning reserve auction or other
14        auction conducted by the Midcontinent Independent
15        System Operator.
16            (C) Each contract between a capacity supplier and a
17        Load Serving Entity shall specify that beginning on
18        June 1 of the first delivery year for which the
19        contract is in effect, and continuing for the term of
20        the contract, the amount of capacity being provided by
21        the capacity supplier and purchased by the Load Serving
22        Entity shall be deemed adjusted on a daily basis to be
23        equal to that portion of the total capacity to be
24        supplied by the capacity supplier equal to the load
25        ratio share of the Applicable Electric Utility's
26        retail customers in the Applicable Local Resource Zone

 

 

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1        that are served by the Load Serving Entity to the total
2        Planning Reserve Margin Requirement attributable to
3        the load of the Applicable Electric Utility's retail
4        customers in the Applicable Local Resource Zone on that
5        day.
6            (D) The standard form contracts shall specify the
7        frequency of billing periods and payment remittance
8        periods for the capacity supplier to bill the Load
9        Serving Entity, and the Load Serving Entity to remit
10        payment to the capacity supplier, for the capacity
11        provided by the capacity supplier to the Load Serving
12        Entity under the contract on each day during the
13        billing period. A capacity supplier and a Load Serving
14        Entity may agree to modify their contract to provide
15        for billing and payment remittance periods other than
16        the billing and payment dates specified in the standard
17        form contracts.
18            (E) The standard form contracts shall include
19        provisions relating to the credit, collateral,
20        performance, and dispute resolution obligations of the
21        parties, and other terms and conditions as described in
22        paragraph (2) of subsection (e) of this Section. The
23        provisions in the standard form contracts relating to
24        credit and collateral shall determine the collateral
25        obligations of the Load Serving Entity based on
26        application of metrics relating to the Load Serving

 

 

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1        Entity's financial condition and creditworthiness, the
2        frequency of billing periods and payment remittance
3        periods specified in the contract, and the legal
4        authority of the Load Serving Entity to recover its
5        costs for the capacity from its retail customers. A
6        capacity supplier and a Load Serving Entity may agree
7        to modify these terms in their contract.
8            (F) The standard form contracts shall specify that
9        the capacity supplier shall operate the capacity
10        resource through the end of the contract term, subject
11        to the following provisions:
12                (i) The capacity supplier shall be excused
13            from its performance under the contract for any
14            cause beyond the reasonable control of the
15            capacity supplier, and affecting the capacity
16            resource, that is a force majeure event or
17            condition typically recognized in the electric
18            power industry, which events and conditions shall
19            be set forth in the standard form contract, and
20            which the capacity supplier, by exercise of
21            commercially reasonable efforts, could not
22            reasonably have been expected to avoid and which,
23            by the exercise of commercially reasonable
24            efforts, it has not been able to overcome. The
25            standard form contracts shall provide that in such
26            event, the capacity resource shall be excused from

 

 

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1            performance for the duration of the force majeure
2            condition, and no capacity payments shall be due to
3            the capacity supplier with respect to the capacity
4            resource for the period of non-performance.
5                (ii) The capacity supplier shall be permitted
6            to terminate the contract before the end of the
7            contract term if legislation is enacted into law by
8            the General Assembly that imposes or authorizes a
9            new tax, special assessment, or fee on the
10            generation of electricity, the ownership or
11            leasehold of a capacity resource, or the privilege
12            or occupation of such generation, ownership, or
13            leasehold of capacity resources by the capacity
14            supplier. However, the provisions of this
15            subdivision (ii) do not apply to any generally
16            applicable tax, special assessment or fee, or
17            requirements imposed by federal law.
18                (iii) The capacity supplier shall be permitted
19            to terminate the contract before the end of the
20            contract term if the capacity supplier is required
21            to make capital expenditures on the capacity
22            resource of $5,000,000 or more, or incur
23            additional operating expenses of $2,500,000 or
24            more per year, in order to comply with a federal or
25            State statute or regulation that is enacted
26            subsequent to the date of the capacity procurement

 

 

HB5134- 129 -LRB100 20041 SMS 35323 b

1            event in which the capacity resource was selected.
2        (10) Each Load Serving Entity that is an alternative
3    retail electric supplier shall be allowed to recover and
4    shall be responsible for recovering its costs for capacity
5    incurred under contracts entered into under this
6    subsection (b-5) in accordance with its contracts and
7    arrangements entered into with its customers. A Load
8    Serving Entity that is an Applicable Electric Utility shall
9    recover its costs for capacity incurred under contracts
10    entered into under this subsection (b-5) in accordance with
11    the electric utility's tariff or other cost recovery
12    mechanism approved by the Commission under subsection (l)
13    of this Section.
14        (11) Nothing in this subsection (b-5) is intended to
15    preclude the Agency or the Commission from conducting the
16    procurement events and processes described in this
17    subsection (b-5) in conjunction with other procurement
18    processes described in this Section or Section 1-75 of the
19    Illinois Power Agency Act, to the extent the Agency and the
20    Commission find that approach is appropriate and
21    practicable while allowing the annual capacity procurement
22    plans to be developed and submitted by the Agency and
23    approved by the Commission in accordance with the schedule
24    set forth in subparagraph (B) of paragraph (3) of this
25    subsection (b-5), and allowing the capacity procurement
26    events to be conducted within the time periods specified in

 

 

HB5134- 130 -LRB100 20041 SMS 35323 b

1    this subsection (b-5).
2        (12) It is the intent of this subsection (b-5) that the
3    Agency's and the Commission's implementation of this
4    subsection, including, but not limited to, the timing and
5    number of procurement events and the duration of contracts,
6    shall conform, at a minimum, to any applicable requirements
7    of the MISO Tariff, as the MISO Tariff may be changed,
8    replaced, or superseded from time to time, that are
9    necessary for Load Serving Entities serving retail
10    customers of an Applicable Electric Utility in an
11    Applicable Local Resource Zone to exercise and implement
12    the Fixed Resource Adequacy Plan capacity procurement
13    option, or a successor capacity procurement mechanism.
14    Notwithstanding anything to the contrary, the Agency and
15    the Commission shall have the authority to take all steps
16    necessary to implement this subsection (b-5) consistent
17    with applicable federal tariffs, and as those tariffs may
18    be changed, replaced, or superseded from time to time, to
19    procure capacity for the electric load of retail customers
20    of Applicable Electric Utilities subject to the
21    requirements of this subsection (b-5).
22    (c) The procurement process set forth in Section 1-75 of
23the Illinois Power Agency Act and subsection (e) of this
24Section shall be administered by a procurement administrator
25and monitored by a procurement monitor. Provided, beginning
26with the delivery year commencing June 1, 2019, that if and to

 

 

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1the extent a provision of subsection (b-5) of this Section is
2inconsistent with a provision of Section 1-75 of the Illinois
3Power Agency Act or of another subsection of this Section, the
4provision of subsection (b-5) shall control and shall be
5applied for purposes of capacity procurement plans and capacity
6procurement processes conducted under subsection (b-5).
7        (1) The procurement administrator shall:
8            (i) design the final procurement process in
9        accordance with Section 1-75 of the Illinois Power
10        Agency Act and subsection (e) of this Section following
11        Commission approval of the procurement plan;
12            (ii) develop benchmarks in accordance with
13        subsection (e)(3) to be used to evaluate bids; these
14        benchmarks shall be submitted to the Commission for
15        review and approval on a confidential basis prior to
16        the procurement event;
17            (iii) serve as the interface between the electric
18        utility and suppliers;
19            (iv) manage the bidder pre-qualification and
20        registration process;
21            (v) obtain the electric utilities' agreement to
22        the final form of all supply contracts and credit
23        collateral agreements;
24            (vi) administer the request for proposals process;
25            (vii) have the discretion to negotiate to
26        determine whether bidders are willing to lower the

 

 

HB5134- 132 -LRB100 20041 SMS 35323 b

1        price of bids that meet the benchmarks approved by the
2        Commission; any post-bid negotiations with bidders
3        shall be limited to price only and shall be completed
4        within 24 hours after opening the sealed bids and shall
5        be conducted in a fair and unbiased manner; in
6        conducting the negotiations, there shall be no
7        disclosure of any information derived from proposals
8        submitted by competing bidders; if information is
9        disclosed to any bidder, it shall be provided to all
10        competing bidders;
11            (viii) maintain confidentiality of supplier and
12        bidding information in a manner consistent with all
13        applicable laws, rules, regulations, and tariffs;
14            (ix) submit a confidential report to the
15        Commission recommending acceptance or rejection of
16        bids;
17            (x) notify the utility of contract counterparties
18        and contract specifics; and
19            (xi) administer related contingency procurement
20        events.
21        (2) The procurement monitor, who shall be retained by
22    the Commission, shall:
23            (i) monitor interactions among the procurement
24        administrator, suppliers, and utility;
25            (ii) monitor and report to the Commission on the
26        progress of the procurement process;

 

 

HB5134- 133 -LRB100 20041 SMS 35323 b

1            (iii) provide an independent confidential report
2        to the Commission regarding the results of the
3        procurement event;
4            (iv) assess compliance with the procurement plans
5        approved by the Commission for each utility that on
6        December 31, 2005 provided electric service to at least
7        100,000 customers in Illinois and for each small
8        multi-jurisdictional utility that on December 31, 2005
9        served less than 100,000 customers in Illinois;
10            (v) preserve the confidentiality of supplier and
11        bidding information in a manner consistent with all
12        applicable laws, rules, regulations, and tariffs;
13            (vi) provide expert advice to the Commission and
14        consult with the procurement administrator regarding
15        issues related to procurement process design, rules,
16        protocols, and policy-related matters; and
17            (vii) consult with the procurement administrator
18        regarding the development and use of benchmark
19        criteria, standard form contracts, credit policies,
20        and bid documents.
21    (d) Except as provided in subsection (j), or as otherwise
22provided in subsection (b-5) for capacity procurement plans and
23capacity procurement processes to be developed and conducted as
24required by subsection (b-5), the planning process shall be
25conducted as follows:
26        (1) Beginning in 2008, each Illinois utility procuring

 

 

HB5134- 134 -LRB100 20041 SMS 35323 b

1    power pursuant to this Section shall annually provide a
2    range of load forecasts to the Illinois Power Agency by
3    July 15 of each year, or such other date as may be required
4    by the Commission or Agency. The load forecasts shall cover
5    the 5-year procurement planning period for the next
6    procurement plan and shall include hourly data
7    representing a high-load, low-load, and expected-load
8    scenario for the load of those retail customers included in
9    the plan's electric supply service requirements. The
10    utility shall provide supporting data and assumptions for
11    each of the scenarios.
12        (2) Beginning in 2008, the Illinois Power Agency shall
13    prepare a procurement plan by August 15th of each year, or
14    such other date as may be required by the Commission. The
15    procurement plan shall identify the portfolio of
16    demand-response and power and energy products to be
17    procured. Cost-effective demand-response measures shall be
18    procured as set forth in item (iii) of subsection (b) of
19    this Section. Copies of the procurement plan shall be
20    posted and made publicly available on the Agency's and
21    Commission's websites, and copies shall also be provided to
22    each affected electric utility. An affected utility shall
23    have 30 days following the date of posting to provide
24    comment to the Agency on the procurement plan. Other
25    interested entities also may comment on the procurement
26    plan. All comments submitted to the Agency shall be

 

 

HB5134- 135 -LRB100 20041 SMS 35323 b

1    specific, supported by data or other detailed analyses,
2    and, if objecting to all or a portion of the procurement
3    plan, accompanied by specific alternative wording or
4    proposals. All comments shall be posted on the Agency's and
5    Commission's websites. During this 30-day comment period,
6    the Agency shall hold at least one public hearing within
7    each utility's service area for the purpose of receiving
8    public comment on the procurement plan. Within 14 days
9    following the end of the 30-day review period, the Agency
10    shall revise the procurement plan as necessary based on the
11    comments received and file the procurement plan with the
12    Commission and post the procurement plan on the websites.
13        (3) Within 5 days after the filing of the procurement
14    plan, any person objecting to the procurement plan shall
15    file an objection with the Commission. Within 10 days after
16    the filing, the Commission shall determine whether a
17    hearing is necessary. The Commission shall enter its order
18    confirming or modifying the procurement plan within 90 days
19    after the filing of the procurement plan by the Illinois
20    Power Agency.
21        (4) The Commission shall approve the procurement plan,
22    including expressly the forecast used in the procurement
23    plan, if the Commission determines that it will ensure
24    adequate, reliable, affordable, efficient, and
25    environmentally sustainable electric service at the lowest
26    total cost over time, taking into account any benefits of

 

 

HB5134- 136 -LRB100 20041 SMS 35323 b

1    price stability. Provided, that for capacity procurement
2    plans developed under subsection (b-5) of this Section, the
3    Commission shall approve the capacity procurement plan, as
4    modified to the extent directed by the Commission, if the
5    Commission determines that the capacity procurement plan
6    conforms to the requirements and objectives of subsection
7    (b-5), including the objective to ensure long-term
8    resource adequacy at the lowest cost over time, taking into
9    account the benefits of price stability and the need to
10    ensure the reliability, adequacy, and resilience of the
11    bulk power generation and delivery system in the Applicable
12    Local Resource Zone.
13    (e) The procurement process shall include each of the
14following components:
15        (1) Solicitation, pre-qualification, and registration
16    of bidders. The procurement administrator shall
17    disseminate information to potential bidders to promote a
18    procurement event, notify potential bidders that the
19    procurement administrator may enter into a post-bid price
20    negotiation with bidders that meet the applicable
21    benchmarks, provide supply requirements, and otherwise
22    explain the competitive procurement process. In addition
23    to such other publication as the procurement administrator
24    determines is appropriate, this information shall be
25    posted on the Illinois Power Agency's and the Commission's
26    websites. The procurement administrator shall also

 

 

HB5134- 137 -LRB100 20041 SMS 35323 b

1    administer the prequalification process, including
2    evaluation of credit worthiness, compliance with
3    procurement rules, and agreement to the standard form
4    contract developed pursuant to paragraph (2) of this
5    subsection (e). The procurement administrator shall then
6    identify and register bidders to participate in the
7    procurement event.
8        (2) Standard contract forms and credit terms and
9    instruments. The procurement administrator, in
10    consultation with the utilities, the Commission, and other
11    interested parties and subject to Commission oversight,
12    shall develop and provide standard contract forms for the
13    supplier contracts that meet generally accepted industry
14    practices. Standard credit terms and instruments that meet
15    generally accepted industry practices shall be similarly
16    developed. The procurement administrator shall make
17    available to the Commission all written comments it
18    receives on the contract forms, credit terms, or
19    instruments. If the procurement administrator cannot reach
20    agreement with the applicable electric utility as to the
21    contract terms and conditions, the procurement
22    administrator must notify the Commission of any disputed
23    terms and the Commission shall resolve the dispute. The
24    terms of the contracts shall not be subject to negotiation
25    by winning bidders, and the bidders must agree to the terms
26    of the contract in advance so that winning bids are

 

 

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1    selected solely on the basis of price.
2        (3) Establishment of a market-based price benchmark.
3    As part of the development of the procurement process, the
4    procurement administrator, in consultation with the
5    Commission staff, Agency staff, and the procurement
6    monitor, shall establish benchmarks for evaluating the
7    final prices in the contracts for each of the products that
8    will be procured through the procurement process. The
9    benchmarks shall be based on price data for similar
10    products for the same delivery period and same delivery
11    hub, or other delivery hubs after adjusting for that
12    difference. The price benchmarks may also be adjusted to
13    take into account differences between the information
14    reflected in the underlying data sources and the specific
15    products and procurement process being used to procure
16    power for the Illinois utilities. The benchmarks shall be
17    confidential but shall be provided to, and will be subject
18    to Commission review and approval, prior to a procurement
19    event.
20        (4) Request for proposals competitive procurement
21    process. The procurement administrator shall design and
22    issue a request for proposals to supply electricity in
23    accordance with each utility's procurement plan, as
24    approved by the Commission. The request for proposals shall
25    set forth a procedure for sealed, binding commitment
26    bidding with pay-as-bid settlement, and provision for

 

 

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1    selection of bids on the basis of price.
2        (5) A plan for implementing contingencies in the event
3    of supplier default or failure of the procurement process
4    to fully meet the expected load requirement due to
5    insufficient supplier participation, Commission rejection
6    of results, or any other cause.
7            (i) Event of supplier default: In the event of
8        supplier default, the utility shall review the
9        contract of the defaulting supplier to determine if the
10        amount of supply is 200 megawatts or greater, and if
11        there are more than 60 days remaining of the contract
12        term. If both of these conditions are met, and the
13        default results in termination of the contract, the
14        utility shall immediately notify the Illinois Power
15        Agency that a request for proposals must be issued to
16        procure replacement power, and the procurement
17        administrator shall run an additional procurement
18        event. If the contracted supply of the defaulting
19        supplier is less than 200 megawatts or there are less
20        than 60 days remaining of the contract term, the
21        utility shall procure power and energy from the
22        applicable regional transmission organization market,
23        including ancillary services, capacity, and day-ahead
24        or real time energy, or both, for the duration of the
25        contract term to replace the contracted supply;
26        provided, however, that if a needed product is not

 

 

HB5134- 140 -LRB100 20041 SMS 35323 b

1        available through the regional transmission
2        organization market it shall be purchased from the
3        wholesale market.
4            (ii) Failure of the procurement process to fully
5        meet the expected load requirement: If the procurement
6        process fails to fully meet the expected load
7        requirement due to insufficient supplier participation
8        or due to a Commission rejection of the procurement
9        results, the procurement administrator, the
10        procurement monitor, and the Commission staff shall
11        meet within 10 days to analyze potential causes of low
12        supplier interest or causes for the Commission
13        decision. If changes are identified that would likely
14        result in increased supplier participation, or that
15        would address concerns causing the Commission to
16        reject the results of the prior procurement event, the
17        procurement administrator may implement those changes
18        and rerun the request for proposals process according
19        to a schedule determined by those parties and
20        consistent with Section 1-75 of the Illinois Power
21        Agency Act and this subsection. In any event, a new
22        request for proposals process shall be implemented by
23        the procurement administrator within 90 days after the
24        determination that the procurement process has failed
25        to fully meet the expected load requirement.
26            (iii) In all cases where there is insufficient

 

 

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1        supply provided under contracts awarded through the
2        procurement process to fully meet the electric
3        utility's load requirement, the utility shall meet the
4        load requirement by procuring power and energy from the
5        applicable regional transmission organization market,
6        including ancillary services, capacity, and day-ahead
7        or real time energy, or both; provided, however, that
8        if a needed product is not available through the
9        regional transmission organization market it shall be
10        purchased from the wholesale market.
11        (6) The procurement process described in this
12    subsection is exempt from the requirements of the Illinois
13    Procurement Code, pursuant to Section 20-10 of that Code.
14    (f) Within 2 business days after opening the sealed bids,
15the procurement administrator shall submit a confidential
16report to the Commission. The report shall contain the results
17of the bidding for each of the products along with the
18procurement administrator's recommendation for the acceptance
19and rejection of bids based on the price benchmark criteria and
20other factors observed in the process. The procurement monitor
21also shall submit a confidential report to the Commission
22within 2 business days after opening the sealed bids. The
23report shall contain the procurement monitor's assessment of
24bidder behavior in the process as well as an assessment of the
25procurement administrator's compliance with the procurement
26process and rules. The Commission shall review the confidential

 

 

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1reports submitted by the procurement administrator and
2procurement monitor, and shall accept or reject the
3recommendations of the procurement administrator within 2
4business days after receipt of the reports.
5    (g) Within 3 business days after the Commission decision
6approving the results of a procurement event, the utility, and
7in the case of a capacity procurement event under subsection
8(b-5) of this Section, all Load-Serving Entities in the
9Applicable Local Resource Zone, shall enter into binding
10contractual arrangements with the winning suppliers using the
11standard form contracts; except that the utility shall not be
12required either directly or indirectly to execute the contracts
13if a tariff that is consistent with subsection (l) of this
14Section has not been approved and placed into effect for that
15utility.
16    (h) The names of the successful bidders and the load
17weighted average of the winning bid prices for each contract
18type and for each contract term shall be made available to the
19public at the time of Commission approval of a procurement
20event. The Commission, the procurement monitor, the
21procurement administrator, the Illinois Power Agency, and all
22participants in the procurement process shall maintain the
23confidentiality of all other supplier and bidding information
24in a manner consistent with all applicable laws, rules,
25regulations, and tariffs. Confidential information, including
26the confidential reports submitted by the procurement

 

 

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1administrator and procurement monitor pursuant to subsection
2(f) of this Section, shall not be made publicly available and
3shall not be discoverable by any party in any proceeding,
4absent a compelling demonstration of need, nor shall those
5reports be admissible in any proceeding other than one for law
6enforcement purposes.
7    (i) Within 2 business days after a Commission decision
8approving the results of a procurement event or such other date
9as may be required by the Commission from time to time, the
10utility shall file for informational purposes with the
11Commission its actual or estimated retail supply charges, as
12applicable, by customer supply group reflecting the costs
13associated with the procurement and computed in accordance with
14the tariffs filed pursuant to subsection (l) of this Section
15and approved by the Commission.
16    (j) Within 60 days following August 28, 2007 (the effective
17date of Public Act 95-481), each electric utility that on
18December 31, 2005 provided electric service to at least 100,000
19customers in Illinois shall prepare and file with the
20Commission an initial procurement plan, which shall conform in
21all material respects to the requirements of the procurement
22plan set forth in subsection (b); provided, however, that the
23Illinois Power Agency Act shall not apply to the initial
24procurement plan prepared pursuant to this subsection. The
25initial procurement plan shall identify the portfolio of power
26and energy products to be procured and delivered for the period

 

 

HB5134- 144 -LRB100 20041 SMS 35323 b

1June 2008 through May 2009, and shall identify the proposed
2procurement administrator, who shall have the same experience
3and expertise as is required of a procurement administrator
4hired pursuant to Section 1-75 of the Illinois Power Agency
5Act. Copies of the procurement plan shall be posted and made
6publicly available on the Commission's website. The initial
7procurement plan may include contracts for renewable resources
8that extend beyond May 2009.
9        (i) Within 14 days following filing of the initial
10    procurement plan, any person may file a detailed objection
11    with the Commission contesting the procurement plan
12    submitted by the electric utility. All objections to the
13    electric utility's plan shall be specific, supported by
14    data or other detailed analyses. The electric utility may
15    file a response to any objections to its procurement plan
16    within 7 days after the date objections are due to be
17    filed. Within 7 days after the date the utility's response
18    is due, the Commission shall determine whether a hearing is
19    necessary. If it determines that a hearing is necessary, it
20    shall require the hearing to be completed and issue an
21    order on the procurement plan within 60 days after the
22    filing of the procurement plan by the electric utility.
23        (ii) The order shall approve or modify the procurement
24    plan, approve an independent procurement administrator,
25    and approve or modify the electric utility's tariffs that
26    are proposed with the initial procurement plan. The

 

 

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1    Commission shall approve the procurement plan if the
2    Commission determines that it will ensure adequate,
3    reliable, affordable, efficient, and environmentally
4    sustainable electric service at the lowest total cost over
5    time, taking into account any benefits of price stability.
6    (k) (Blank).
7    (k-5) (Blank).
8    (l) An electric utility shall recover its costs incurred
9under this Section, including, but not limited to, its costs
10for capacity procured under subsection (b-5) of this Section,
11and the costs of procuring power and energy demand-response
12resources under this Section. The utility shall file with the
13initial procurement plan its proposed tariffs through which its
14costs of procuring power that are incurred pursuant to a
15Commission-approved procurement plan and those other costs
16identified in this subsection (l), will be recovered. The
17tariffs shall include a formula rate or charge designed to pass
18through both the costs incurred by the utility in procuring a
19supply of electric power and energy for the applicable customer
20classes with no mark-up or return on the price paid by the
21utility for that supply, plus any just and reasonable costs
22that the utility incurs in arranging and providing for the
23supply of electric power and energy. The formula rate or charge
24shall also contain provisions that ensure that its application
25does not result in over or under recovery due to changes in
26customer usage and demand patterns, and that provide for the

 

 

HB5134- 146 -LRB100 20041 SMS 35323 b

1correction, on at least an annual basis, of any accounting
2errors that may occur. A utility shall recover through the
3tariff all reasonable costs incurred to implement or comply
4with any procurement plan that is developed and put into effect
5pursuant to Section 1-75 of the Illinois Power Agency Act and
6this Section, including any fees assessed by the Illinois Power
7Agency, costs associated with load balancing, and contingency
8plan costs. The electric utility shall also recover its full
9costs of procuring electric supply for which it contracted
10before the effective date of this Section in conjunction with
11the provision of full requirements service under fixed-price
12bundled service tariffs subsequent to December 31, 2006. All
13such costs shall be deemed to have been prudently incurred. The
14pass-through tariffs that are filed and approved pursuant to
15this Section shall not be subject to review under, or in any
16way limited by, Section 16-111(i) of this Act. All of the costs
17incurred by the electric utility associated with the purchase
18of zero emission credits in accordance with subsection (d-5) of
19Section 1-75 of the Illinois Power Agency Act and, beginning
20June 1, 2017, all of the costs incurred by the electric utility
21associated with the purchase of renewable energy resources in
22accordance with Sections 1-56 and 1-75 of the Illinois Power
23Agency Act, shall be recovered through the electric utility's
24tariffed charges applicable to all of its retail customers, as
25specified in subsection (k) of Section 16-108 of this Act, and
26shall not be recovered through the electric utility's tariffed

 

 

HB5134- 147 -LRB100 20041 SMS 35323 b

1charges for electric power and energy supply to its eligible
2retail customers.
3    (m) The Commission has the authority to adopt rules to
4carry out the provisions of this Section. For the public
5interest, safety, and welfare, the Commission also has
6authority to adopt rules to carry out the provisions of this
7Section on an emergency basis immediately following August 28,
82007 (the effective date of Public Act 95-481).
9    (n) Notwithstanding any other provision of this Act, any
10affiliated electric utilities that submit a single procurement
11plan covering their combined needs may procure for those
12combined needs in conjunction with that plan, and may enter
13jointly into power supply contracts, purchases, and other
14procurement arrangements, and allocate capacity and energy and
15cost responsibility therefor among themselves in proportion to
16their requirements.
17    (o) On or before June 1 of each year, the Commission shall
18hold an informal hearing for the purpose of receiving comments
19on the prior year's procurement process and any recommendations
20for change.
21    (p) An electric utility subject to this Section may propose
22to invest, lease, own, or operate an electric generation
23facility as part of its procurement plan, provided the utility
24demonstrates that such facility is the least-cost option to
25provide electric service to those retail customers included in
26the plan's electric supply service requirements. If the

 

 

HB5134- 148 -LRB100 20041 SMS 35323 b

1facility is shown to be the least-cost option and is included
2in a procurement plan prepared in accordance with Section 1-75
3of the Illinois Power Agency Act and this Section, then the
4electric utility shall make a filing pursuant to Section 8-406
5of this Act, and may request of the Commission any statutory
6relief required thereunder. If the Commission grants all of the
7necessary approvals for the proposed facility, such supply
8shall thereafter be considered as a pre-existing contract under
9subsection (b) of this Section. The Commission shall in any
10order approving a proposal under this subsection specify how
11the utility will recover the prudently incurred costs of
12investing in, leasing, owning, or operating such generation
13facility through just and reasonable rates charged to those
14retail customers included in the plan's electric supply service
15requirements. Cost recovery for facilities included in the
16utility's procurement plan pursuant to this subsection shall
17not be subject to review under or in any way limited by the
18provisions of Section 16-111(i) of this Act. Nothing in this
19Section is intended to prohibit a utility from filing for a
20fuel adjustment clause as is otherwise permitted under Section
219-220 of this Act.
22    (q) If the Illinois Power Agency filed with the Commission,
23under Section 16-111.5 of this Act, its proposed procurement
24plan for the period commencing June 1, 2017, and the Commission
25has not yet entered its final order approving the plan on or
26before the effective date of this amendatory Act of the 99th

 

 

HB5134- 149 -LRB100 20041 SMS 35323 b

1General Assembly, then the Illinois Power Agency shall file a
2notice of withdrawal with the Commission, after the effective
3date of this amendatory Act of the 99th General Assembly, to
4withdraw the proposed procurement of renewable energy
5resources to be approved under the plan, other than the
6procurement of renewable energy credits from distributed
7renewable energy generation devices using funds previously
8collected from electric utilities' retail customers that take
9service pursuant to electric utilities' hourly pricing tariff
10or tariffs and, for an electric utility that serves less than
11100,000 retail customers in the State, other than the
12procurement of renewable energy credits from distributed
13renewable energy generation devices. Upon receipt of the
14notice, the Commission shall enter an order that approves the
15withdrawal of the proposed procurement of renewable energy
16resources from the plan. The initially proposed procurement of
17renewable energy resources shall not be approved or be the
18subject of any further hearing, investigation, proceeding, or
19order of any kind.
20    This amendatory Act of the 99th General Assembly preempts
21and supersedes any order entered by the Commission that
22approved the Illinois Power Agency's procurement plan for the
23period commencing June 1, 2017, to the extent it is
24inconsistent with the provisions of this amendatory Act of the
2599th General Assembly. To the extent any previously entered
26order approved the procurement of renewable energy resources,

 

 

HB5134- 150 -LRB100 20041 SMS 35323 b

1the portion of that order approving the procurement shall be
2void, other than the procurement of renewable energy credits
3from distributed renewable energy generation devices using
4funds previously collected from electric utilities' retail
5customers that take service under electric utilities' hourly
6pricing tariff or tariffs and, for an electric utility that
7serves less than 100,000 retail customers in the State, other
8than the procurement of renewable energy credits for
9distributed renewable energy generation devices.
10(Source: P.A. 99-906, eff. 6-1-17.)
 
11    (220 ILCS 5/16-115A)
12    Sec. 16-115A. Obligations of alternative retail electric
13suppliers.
14    (a) An alternative retail electric supplier shall:
15        (i) comply with the requirements imposed on public
16    utilities by Sections 8-201 through 8-207, 8-301, 8-505 and
17    8-507 of this Act, to the extent that these Sections have
18    application to the services being offered by the
19    alternative retail electric supplier; and
20        (ii) continue to comply with the requirements for
21    certification stated in subsection (d) of Section 16-115;
22    and .
23        (iii) for delivery years commencing on and after June
24    1, 2019, comply with the requirements of subsection (h) of
25    this Section and of subsection (b-5) of Section 16-111.5 of

 

 

HB5134- 151 -LRB100 20041 SMS 35323 b

1    this Act.
2    (b) An alternative retail electric supplier shall obtain
3verifiable authorization from a customer, in a form or manner
4approved by the Commission consistent with Section 2EE of the
5Consumer Fraud and Deceptive Business Practices Act, before the
6customer is switched from another supplier.
7    (c) No alternative retail electric supplier, or electric
8utility other than the electric utility in whose service area a
9customer is located, shall (i) enter into or employ any
10arrangements which have the effect of preventing a retail
11customer with a maximum electrical demand of less than one
12megawatt from having access to the services of the electric
13utility in whose service area the customer is located or (ii)
14charge retail customers for such access. This subsection shall
15not be construed to prevent an arms-length agreement between a
16supplier and a retail customer that sets a term of service,
17notice period for terminating service and provisions governing
18early termination through a tariff or contract as allowed by
19Section 16-119.
20    (d) An alternative retail electric supplier that is
21certified to serve residential or small commercial retail
22customers shall not:
23        (1) deny service to a customer or group of customers
24    nor establish any differences as to prices, terms,
25    conditions, services, products, facilities, or in any
26    other respect, whereby such denial or differences are based

 

 

HB5134- 152 -LRB100 20041 SMS 35323 b

1    upon race, gender or income.
2        (2) deny service to a customer or group of customers
3    based on locality nor establish any unreasonable
4    difference as to prices, terms, conditions, services,
5    products, or facilities as between localities.
6    (e) An alternative retail electric supplier shall comply
7with the following requirements with respect to the marketing,
8offering and provision of products or services to residential
9and small commercial retail customers:
10        (i) Any marketing materials which make statements
11    concerning prices, terms and conditions of service shall
12    contain information that adequately discloses the prices,
13    terms and conditions of the products or services that the
14    alternative retail electric supplier is offering or
15    selling to the customer.
16        (ii) Before any customer is switched from another
17    supplier, the alternative retail electric supplier shall
18    give the customer written information that adequately
19    discloses, in plain language, the prices, terms and
20    conditions of the products and services being offered and
21    sold to the customer.
22        (iii) An alternative retail electric supplier shall
23    provide documentation to the Commission and to customers
24    that substantiates any claims made by the alternative
25    retail electric supplier regarding the technologies and
26    fuel types used to generate the electricity offered or sold

 

 

HB5134- 153 -LRB100 20041 SMS 35323 b

1    to customers.
2        (iv) The alternative retail electric supplier shall
3    provide to the customer (1) itemized billing statements
4    that describe the products and services provided to the
5    customer and their prices, and (2) an additional statement,
6    at least annually, that adequately discloses the average
7    monthly prices, and the terms and conditions, of the
8    products and services sold to the customer.
9    (f) An alternative retail electric supplier may limit the
10overall size or availability of a service offering by
11specifying one or more of the following: a maximum number of
12customers, maximum amount of electric load to be served, time
13period during which the offering will be available, or other
14comparable limitation, but not including the geographic
15locations of customers within the area which the alternative
16retail electric supplier is certificated to serve. The
17alternative retail electric supplier shall file the terms and
18conditions of such service offering including the applicable
19limitations with the Commission prior to making the service
20offering available to customers.
21    (g) Nothing in this Section shall be construed as
22preventing an alternative retail electric supplier, which is an
23affiliate of, or which contracts with, (i) an industry or trade
24organization or association, (ii) a membership organization or
25association that exists for a purpose other than the purchase
26of electricity, or (iii) another organization that meets

 

 

HB5134- 154 -LRB100 20041 SMS 35323 b

1criteria established in a rule adopted by the Commission, from
2offering through the organization or association services at
3prices, terms and conditions that are available solely to the
4members of the organization or association.
5    (h) Notwithstanding any provision to the contrary in this
6Act or the Illinois Power Agency Act, beginning with the
7delivery year commencing June 1, 2019, an alternative retail
8electric supplier shall use only capacity procured and
9allocated to the alternative retail electric supplier through
10the processes specified in subsection (b-5) of Section 16-111.5
11of this Act to serve retail customers of an Applicable Electric
12Utility in an Applicable Local Resource Zone in this State;
13provided, that an alternative electric retail supplier may
14procure through other means any capacity needed to serve the
15load requirements of retail customers of an Applicable Electric
16Utility in an Applicable Local Resource Zone in excess of the
17capacity procured and allocated to the alternative retail
18electric supplier under subsection (b-5) of Section 16-111.5.
19An alternative retail electric supplier shall enter into
20contracts for capacity, in the form adopted by the procurement
21administrator and conforming to the requirements of subsection
22(b-5) of Section 16-111.5 of this Act, with capacity suppliers
23selected in capacity procurement events conducted under
24subsection (b-5) of Section 16-111.5. An alternative retail
25electric supplier shall take those actions that are necessary
26(i) to participate in capacity procurement events conducted

 

 

HB5134- 155 -LRB100 20041 SMS 35323 b

1under subsection (b-5) of Section 16-111.5 of this Act; and
2(ii) to participate in the Fixed Resource Adequacy Plan
3capacity procurement option, or a successor capacity
4procurement mechanism, under the MISO Tariff using the capacity
5procured in capacity procurement events conducted, and
6allocated to the alternative retail electric supplier, under
7subsection (b-5) of Section 16-111.5 of this Act.
8    As a condition of the continued effectiveness of the
9certificate of service authority of an alternative retail
10electric supplier that serves retail customers of an Applicable
11Electric Utility in an Applicable Local Resource Zone, the
12alternative retail electric supplier shall certify its
13compliance with the requirements of this subsection (h) in its
14annual reports to the Commission. The Commission shall initiate
15a proceeding to revoke the certificate of service authority of
16any alternative retail electric supplier that is required by
17this subsection (h) to, but does not, certify its compliance
18with the requirements of this subsection (h) in an annual
19report to the Commission or that the Commission has reason to
20believe has failed or is failing to comply with the
21requirements of this subsection (h). No certificate of service
22authority shall be revoked under this subsection (h) unless and
23until the alternative retail electric supplier has received
24notice of the proceeding and the grounds on which the
25Commission proposes to revoke the certificate of service
26authority, and has been provided opportunity for a hearing.

 

 

HB5134- 156 -LRB100 20041 SMS 35323 b

1    For purposes of this subsection (h), the terms "Applicable
2Electric Utility", "Fixed Resource Adequacy Plan", "Contracted
3LSE Capacity", and "MISO Tariff" shall have the meanings set
4forth in subsection (b-5) of Section 16-111.5 of this Act, and
5the term "Applicable Local Resource Zone" shall have the
6meaning set forth in Section 1-75 of the Illinois Power Agency
7Act.
8(Source: P.A. 90-561, eff. 12-16-97.)
 
9    Section 99. Effective date. This Act takes effect upon
10becoming law.