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1 | | that incentivizes renewable development and other |
2 | | carbon-reducing policies, such as energy efficiency, while |
3 | | ensuring that the benefits and opportunities of a carbon-free |
4 | | future are accessible in economically disadvantaged |
5 | | communities, environmental justice communities, and |
6 | | communities of color. |
7 | | (c) In the wake of federal reversals on climate action, the |
8 | | State of Illinois should pursue immediate action on policies |
9 | | that will ensure a just and responsible phase out of fossil |
10 | | fuels from the power sector to reduce harmful emissions from |
11 | | Illinois power plants, support power plant communities and |
12 | | workers, and allow the clean energy economy to continue growing |
13 | | in every corner of Illinois. |
14 | | (d) Energy efficiency should form the basis of any robust |
15 | | clean energy policy. It is the cheapest clean energy resource, |
16 | | and efficiency upgrades help customers manage their energy |
17 | | bills directly by reducing the energy they need, and indirectly |
18 | | by holding demand and prices down statewide. |
19 | | (e) The transportation sector is now the leading source of |
20 | | carbon pollution in Illinois, responsible for roughly |
21 | | one-third of all carbon emissions. The State of Illinois should |
22 | | set forth an ambitious goal to remove the equivalent of 1 |
23 | | million gasoline and diesel-powered vehicles from our roads by |
24 | | quickly implementing new policies that expand access to |
25 | | transit, promote walking and biking mobility, and increase |
26 | | electric vehicle adoption. If managed appropriately, electric |
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1 | | vehicle adoption will drastically reduce emissions from |
2 | | transportation, and could save Illinois residents billions of |
3 | | dollars. |
4 | | (f) In addition to better air quality and safer climate, |
5 | | Illinois residents that do not use electric vehicles also |
6 | | benefit from greater adoption through lower electric bills |
7 | | resulting from the greater utilization of the electric grid |
8 | | during off-peak hours. |
9 | | (g) Energy storage, such as batteries, can provide many |
10 | | services to the electricity grid which benefit the grid, |
11 | | including managing (or shaving) peak load, frequency |
12 | | regulation, voltage support, reserve capacity, and black-start |
13 | | capability. And, if that storage facilitates greater |
14 | | utilization of renewables, it can allow for more clean energy |
15 | | to be accessible, reduce pollution, and provide multiple |
16 | | benefits. |
17 | | (h) Illinois needs to adopt a broad-based policy approach |
18 | | to decarbonize Illinois' electric sector (both how much we |
19 | | produce and how much we consume) in a just and equitable way |
20 | | that puts our State on track to phase out emitting power plants |
21 | | by 2030. |
22 | | (i) Illinois' policy approach must ensure the reduction of |
23 | | co-pollutant emissions that cause serious, local health |
24 | | impacts, prioritizing environmental justice communities near |
25 | | power plants. |
26 | | (j) As we decarbonize Illinois' electric sector, Illinois |
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1 | | must create new investment to stimulate the economic and |
2 | | environmental well-being of communities disproportionately |
3 | | impacted by the historical operation of, and recent or expected |
4 | | closures of, fossil fuel power plants.
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5 | | Article 5. |
6 | | Clean Jobs Workforce Hubs Act |
7 | | Section 5-1. Short title. This Article may be cited as the |
8 | | Clean Jobs Workforce Hubs Act. References in this Article to |
9 | | "this Act" mean
this Article. |
10 | | Section 5-5. Legislative purpose. The General Assembly |
11 | | finds that the State of Illinois should build upon the success |
12 | | of the Future Energy Jobs Act and the Illinois Solar for All |
13 | | Program by further expanding equitable access to quality jobs |
14 | | and economic opportunities (especially for residents of |
15 | | economically disadvantaged communities, environmental justice |
16 | | communities, communities of color, returning citizens, foster |
17 | | care communities, and other underserved communities who have |
18 | | had to bear the disproportionate burden of dirty fossil fuel |
19 | | pollution) across the entire clean energy sector in Illinois, |
20 | | including solar, wind, energy efficiency, transportation |
21 | | electrification, and other related clean energy industries.
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22 | | Section 5-10. Definitions. As used in this Act: |
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1 | | "Department" means the Department of Commerce and Economic |
2 | | Opportunity. |
3 | | "Director" means the Director of Commerce and Economic |
4 | | Opportunity. |
5 | | "Environmental justice communities" means the proposed |
6 | | definition of that term based on existing methodologies and |
7 | | findings used by the Illinois Power Agency and its |
8 | | Administrator in its Illinois Solar for All Program. |
9 | | "Program" means the Clean Jobs Workforce Hubs Program. |
10 | | Section 5-15. Clean Jobs Workforce Hubs Program. The |
11 | | Department must develop and administer the Clean Jobs Workforce |
12 | | Hubs Program to create a network of frontline organizations |
13 | | across the State that provide direct and sustained support for |
14 | | members of economically disadvantaged communities, |
15 | | environmental justice communities, communities of color, |
16 | | returning citizens, foster care communities, and displaced |
17 | | fossil fuel workers to enter and complete the pipeline for |
18 | | clean energy jobs in solar energy, wind energy, energy |
19 | | efficiency, electric vehicles and related industries. The |
20 | | Clean Jobs Workforce Hubs Program must: |
21 | | (1) leverage frontline organizations to ensure members |
22 | | of disadvantaged communities across the State have |
23 | | dedicated and sustained support to enter and complete the |
24 | | career pipeline for clean energy jobs; and
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25 | | (2) develop formal partnerships between frontline |
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1 | | organizations and trades groups, labor unions, and clean |
2 | | energy employers to ensure Clean Jobs Workforce Hubs |
3 | | Program participants have priority access to |
4 | | pre-apprenticeship, apprenticeship, and other employment |
5 | | opportunities.
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6 | | Section 5-20. Clean Jobs Workforce Hubs Network. The Clean |
7 | | Jobs Workforce Hubs Network, made up of frontline organizations |
8 | | across the State and administered by a Program Administrator, |
9 | | is required to provide the following: |
10 | | (1) community education and outreach about workforce |
11 | | and training opportunities to ensure members of |
12 | | economically disadvantaged communities, environmental |
13 | | justice communities, communities of color, returning |
14 | | citizens, foster care communities, and displaced fossil |
15 | | fuel workers understand clean energy workforce and |
16 | | training opportunities; |
17 | | (2) training, apprenticeship, job readiness, and skill |
18 | | development, including soft skills, math skills, technical |
19 | | skills, and other development needed for members of |
20 | | economically disadvantaged communities, environmental |
21 | | justice communities, communities of color, returning |
22 | | citizens, foster care communities, and displaced fossil |
23 | | fuel workers to enter clean energy-related training and |
24 | | apprenticeship programs and career paths; |
25 | | (3) targeted outreach and recruitment to ensure people |
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1 | | of color are invited, supported, and given preference in |
2 | | applying for both community-based and labor-based training |
3 | | opportunities, including apprenticeship and |
4 | | pre-apprenticeship programs; |
5 | | (4) the development of partnerships with labor |
6 | | organizations to ensure Clean Jobs Workforce Hubs |
7 | | participants are recruited, placed, and supported in |
8 | | labor-based training programs, such as workforce |
9 | | development programs and pre-apprenticeship and |
10 | | apprenticeship programs; |
11 | | (5) a stipend program for Clean Jobs Workforce Hubs |
12 | | participants in clean energy-related training programs and |
13 | | company apprenticeships, including providing funding to |
14 | | assist with transportation, child care, and other needed |
15 | | services and supplies during the length of programs; and |
16 | | (6) direct assistance and counseling to participants |
17 | | in training and apprenticeship programs to help connect |
18 | | trainees to both union and non-union career options with |
19 | | renewable energy companies, energy efficiency companies, |
20 | | and other clean energy employers and to provide a direct |
21 | | resource for industry to identify qualified workers to meet |
22 | | program hiring or subcontracting requirements, including |
23 | | the workforce equity building actions required under |
24 | | Section 1-75 of the Illinois Power Agency Act and Section |
25 | | 16-128B of the Public Utilities Act. Placement activities |
26 | | should include outreach to public agencies, utilities, and |
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1 | | clean energy companies, creation of formal partnerships |
2 | | with employers, job interview preparation, and on-the-job |
3 | | support and counseling.
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4 | | Section 5-25. Program Administrator. Within 60 days after |
5 | | the effective date of this Act and after a comprehensive |
6 | | stakeholder process that includes representatives from |
7 | | frontline communities, the Department shall select a Program |
8 | | Administrator, as an individual or an organization, to |
9 | | coordinate the work of all or a portion of the work of the |
10 | | Clean Jobs Workforce Hubs. The Program Administrator shall have |
11 | | strong capabilities in program management, knowledge of |
12 | | industry trends and activities, workforce development best |
13 | | practices, and community development. The Program |
14 | | Administrator shall coordinate the work of all or a portion of |
15 | | the Clean Jobs Workforce Hubs network to ensure consistent |
16 | | execution, performance, partnerships, marketing, and program |
17 | | access across the State. |
18 | | Section 5-30. Clean jobs curriculum. |
19 | | (a) Within 60 days after the effective date of this Act, |
20 | | the Department must convene a comprehensive stakeholder |
21 | | process that includes representatives from the Illinois State |
22 | | Board of Education, the Illinois Community College Board, the |
23 | | Illinois Department of Labor, frontline organizations, |
24 | | workforce development providers, labor unions, building |
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1 | | trades, clean energy employers, including solar industry, wind |
2 | | industry, energy efficiency, and transportation |
3 | | electrification, and other needed participants to identify the |
4 | | career pathways and training curriculum (such as the |
5 | | Multi-Craft Core Curriculum) needed to prepare workers to enter |
6 | | the clean energy field, including solar photovoltaic, solar |
7 | | thermal, wind energy, energy efficiency, site assessment, |
8 | | sales, and back office. Curriculum must also include broad |
9 | | occupational training to provide career entry into the general |
10 | | construction and building trades sector. Within 120 days after |
11 | | the stakeholder process is convened, the Department must |
12 | | publish a report that reflects the findings and core curriculum |
13 | | recommendations developed by the stakeholder group. |
14 | | (b) Organizations that receive funding to provide training |
15 | | under the Clean Jobs Workforce Hubs Program, including |
16 | | community-based and labor-based training providers, must use |
17 | | the core curriculum that is developed under subsection (a).
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18 | | Section 5-35. Administration; rules. The Department shall |
19 | | administer this Act and shall adopt any rules necessary for |
20 | | that purpose. |
21 | | Article 10. |
22 | | Expanding Clean Energy Entrepreneurship Act |
23 | | Section 10-1. Short title. This Article may be cited as the |
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1 | | Expanding Clean Energy Entrepreneurship Act. References in |
2 | | this Article to "this Act" mean
this Article. |
3 | | Section 10-5. Legislative purpose. The General Assembly |
4 | | finds that the State of Illinois should build upon the success |
5 | | of the Future Energy Jobs Act and the Illinois Solar for All |
6 | | Program by supporting small, disadvantaged clean energy |
7 | | businesses and contractors having equitable access to economic |
8 | | opportunities created by the growing clean energy sector in |
9 | | Illinois.
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10 | | Section 10-10. Definitions. As used in this Act: |
11 | | "Department" means the Department of Commerce and Economic |
12 | | Opportunity.
"Director" means the Director of Commerce and |
13 | | Economic Opportunity. |
14 | | "Disadvantaged businesses and contractors" means an entity |
15 | | defined under Section 2 of the Business Enterprise for |
16 | | Minorities, Women, and Persons with Disabilities Act.
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17 | | "Environmental justice communities" means the proposed |
18 | | definition of that term based on existing methodologies and |
19 | | findings used by the Illinois Power Agency and its |
20 | | Administrator in its Illinois Solar for All Program. |
21 | | "Program" means the Expanding Clean Energy |
22 | | Entrepreneurship and Contractor Incubator Program. |
23 | | Section 10-15. Expanding Clean Energy Entrepreneurship and |
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1 | | Contractor Incubator Program. The Department must develop and |
2 | | administer the Expanding Clean Energy Entrepreneurship and |
3 | | Contractor Incubator Program to support the development of |
4 | | disadvantaged businesses and contractors and provide the |
5 | | needed resources for such businesses to be able to effectively |
6 | | compete for, gain, and execute clean energy-related projects. |
7 | | The Program must provide: |
8 | | (1) Access to low-cost capital for small and |
9 | | disadvantaged clean energy businesses and contractors to |
10 | | be able to complete on a level playing field with more |
11 | | established, capitalized businesses across the entire |
12 | | clean energy sector in Illinois, including solar, wind, |
13 | | energy efficiency, transportation electrification, and |
14 | | other clean energy industries. |
15 | | (2) Support for obtaining the necessary insurance, |
16 | | bonding, back office services, permits, certifications, |
17 | | and other financial assurance requirements needed to |
18 | | effectively compete for clean energy-related projects, |
19 | | incentive programs, and approved vendor and qualified |
20 | | installer opportunities. |
21 | | (3) Development and support needed for disadvantaged |
22 | | clean energy contractors to build their business and |
23 | | connect them to specific projects, Approved Vendor |
24 | | subcontracting and qualified installer opportunities, |
25 | | partnerships, networks, capital, and other resources |
26 | | needed to compete for, gain, and execute clean |
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1 | | energy-related project installation and subcontracts. |
2 | | Section 10-20. Program Administrator. Within 60 days after |
3 | | the effective date of this Act, the Department shall select a |
4 | | Program Administrator, as an individual or an organization, to |
5 | | coordinate the work of all or a portion of the work of the |
6 | | Expanding Clean Energy Entrepreneurship and Contractor |
7 | | Incubator Program. The Program Administrator shall have strong |
8 | | capabilities in program management, knowledge of industry |
9 | | trends and activities, disadvantaged business and contractor |
10 | | development best practices, and related development support. |
11 | | The Program Administrator shall coordinate the work of all or a |
12 | | portion of the Program to ensure consistent execution, |
13 | | performance, partnerships, marketing, and program access |
14 | | across the State. |
15 | | Section 10-25. Administration; rules. The Department shall |
16 | | administer this Act and shall adopt any rules necessary for |
17 | | that purpose. |
18 | | Article 15. |
19 | | Community Energy and Climate Planning Act |
20 | | Section 15-1. Short title. This Article may be cited as the |
21 | | Community Energy and Climate Planning Act. References in this |
22 | | Article to "this Act" mean
this Article. |
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1 | | Section 15-5. Legislative purpose. The General Assembly |
2 | | makes the following findings: |
3 | | (1) The health, welfare, and prosperity of Illinois |
4 | | citizens require that Illinois take all steps possible to |
5 | | combat climate change, address harmful environmental |
6 | | impacts deriving from the generation of electricity, |
7 | | ensure affordable utility service, equitable and |
8 | | affordable access to transportation, and clean, safe, |
9 | | affordable housing. |
10 | | (2) The achievement of these goals will depend on |
11 | | strong community engagement to ensure that programs and |
12 | | policy solutions meet the needs of disparate communities. |
13 | | (3) Ensuring that these goals are met without adverse |
14 | | impacts on utility bill affordability, housing |
15 | | affordability, and other essential services will depend on |
16 | | the coordination of policies and programs within local |
17 | | communities.
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18 | | Section 15-10. Definitions. As used in this Act: |
19 | | "Alternative energy improvement" means the installation or |
20 | | upgrade of electrical wiring, outlets, or charging stations to |
21 | | charge a motor vehicle that is fully or partially powered by |
22 | | electricity; photovoltaic, energy storage, or thermal |
23 | | resource; or any combination thereof. |
24 | | "Energy efficiency improvement" means equipment, devices, |
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1 | | or materials intended to decrease energy consumption or promote |
2 | | a more efficient use of electricity, natural gas, propane, or |
3 | | other forms of energy on property, including, but not limited |
4 | | to, all of the following: |
5 | | (1) insulation in walls, roofs, floors, foundations, |
6 | | or heating and cooling distribution systems; |
7 | | (2) storm windows and doors, multi-glazed windows and |
8 | | doors, heat-absorbing or heat-reflective glazed and coated |
9 | | window and door systems, and additional glazing, |
10 | | reductions in glass area, and other window and door system |
11 | | modifications that reduce energy consumption; |
12 | | (3) automated energy control systems; |
13 | | (4) high efficiency heating, ventilating, or |
14 | | air-conditioning and distribution system modifications or |
15 | | replacements; |
16 | | (5) caulking, weather-stripping, and air sealing; |
17 | | (6) replacement or modification of lighting fixtures |
18 | | to reduce the energy use of the lighting system; |
19 | | (7) energy controls or recovery systems; |
20 | | (8) day lighting systems; |
21 | | (9) any energy efficiency project, as defined in |
22 | | Section 825-65 of the Illinois Finance Authority Act; and |
23 | | (10) any other installation or modification of |
24 | | equipment, devices, or materials approved as a utility |
25 | | cost-savings measure by the governing body. |
26 | | "Energy project" means the installation or modification of |
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1 | | an alternative energy improvement, energy efficiency |
2 | | improvement, or water use improvement, or the acquisition, |
3 | | installation, or improvement of a renewable energy system that |
4 | | is affixed to a stabilized existing property (including new |
5 | | construction). |
6 | | "Environmental justice communities" means the proposed |
7 | | definition of that term based on existing methodologies and |
8 | | findings used by the Illinois Power Agency and its |
9 | | Administrator in its Illinois Solar for All Program. |
10 | | "Governing body" means the county board or board of county |
11 | | commissioners of a county, the city council of a city, or the |
12 | | board of trustees of a village. |
13 | | "Local unit of government" means a county, city, or |
14 | | village. |
15 | | "Renewable energy resource" includes energy and its |
16 | | associated renewable energy credit or renewable energy credits |
17 | | from wind energy, solar thermal energy, geothermal energy, |
18 | | photovoltaic cells and panels, biodiesel, anaerobic digestion, |
19 | | and hydropower that does not involve new construction or |
20 | | significant expansion of hydropower dams. For purposes of this |
21 | | Act, landfill gas produced in the State is considered a |
22 | | renewable energy resource. "Renewable energy resource" does |
23 | | not include the incineration or burning of any solid material. |
24 | | "Renewable energy system" means a fixture, product, |
25 | | device, or interacting group of fixtures, products, or devices |
26 | | on the customer's side of the meter that use one or more |
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1 | | renewable energy resources to generate electricity, and |
2 | | specifically includes any renewable energy project, as defined |
3 | | in Section 825-65 of the Illinois Finance Authority Act. |
4 | | "Water use improvement" means any fixture, product, |
5 | | system, device, or interacting group thereof for or serving any |
6 | | property that has the effect of conserving water resources |
7 | | through improved water management, efficiency, or thermal |
8 | | resource. |
9 | | Section 15-15. Community Energy and Climate Plans; |
10 | | creation. |
11 | | (a) Pursuant to the procedures in Section 15-20, a local |
12 | | unit of government may establish Community Energy and Climate |
13 | | Plans and identify boundaries and areas covered by the Plans. |
14 | | (b) Community Energy and Climate Plans are intended to aid |
15 | | local governments develop a comprehensive approach to |
16 | | combining different energy and climate programs and funding |
17 | | resources to achieve complementary impact. An effective |
18 | | planning process shall: |
19 | | (1) help communities discover ways that their local |
20 | | government, businesses, and residents can control their |
21 | | energy use and bills; |
22 | | (2) ensure a cost-effective transition away from |
23 | | fossil fuels in the transportation sector; |
24 | | (3) expand access to workforce development and job |
25 | | training opportunities in the emerging clean energy |
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1 | | economy; |
2 | | (4) promote economic development through improvements |
3 | | in community infrastructure, transit, and support for |
4 | | local business; |
5 | | (5) improve the health of Illinois communities by |
6 | | reducing emissions, addressing existing brownfield areas, |
7 | | and promoting the integration of distributed energy |
8 | | resources; |
9 | | (6) enable greater customer engagement, empowerment, |
10 | | and options for energy services, and ultimately reduce |
11 | | utility bills for Illinoisans; |
12 | | (7) bring the benefits of grid modernization and the |
13 | | deployment of distributed energy resources to economically |
14 | | disadvantaged communities throughout Illinois; and |
15 | | (8) support existing Illinois policy goals promoting |
16 | | energy efficiency, demand response and investments in |
17 | | renewable energy resources.
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18 | | (c) A Community Energy and Climate Plan shall include |
19 | | discussion of:
|
20 | | (1) the demographics of the community, including |
21 | | information on the mix of residential and commercial areas |
22 | | and populations, ages, languages, education and workforce |
23 | | training. This includes an examination of the average |
24 | | utility bills paid within the community by class and census |
25 | | area, the percentage and locations of individuals |
26 | | requiring energy assistance, participation of community |
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1 | | members in other assistance programs. This also includes an |
2 | | examination of the community's energy use, both for |
3 | | electricity, natural gas, and transportation and other |
4 | | fuels; |
5 | | (2) the geography of the community, including the |
6 | | amount of green space, brownfield sites, open space for |
7 | | potential development, location of critical infrastructure |
8 | | such as emergency response facilities, health care and |
9 | | education facilities, and public transportation routes; |
10 | | and |
11 | | (3) information on economic development opportunities, |
12 | | commercial usage, and employment opportunities. |
13 | | (d) A Community Energy and Climate Plan shall address the |
14 | | following areas: |
15 | | (1) distributed energy resources, including energy |
16 | | efficiency, demand response, dynamic pricing, energy |
17 | | storage, solar (thermal, rooftop, and community); |
18 | | (2) building codes (both commercial and residential); |
19 | | (3) vehicle miles traveled; and |
20 | | (4) transit options, including individual car |
21 | | ownership, ride sharing, buses, trains, bicycles, and |
22 | | pedestrian walkways. |
23 | | (e) A Community Energy and Climate Plan will conclude with |
24 | | proposals to: |
25 | | (1) increase the use of electricity as a transportation |
26 | | fuel at multi-unit dwellings; |
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1 | | (2) maximize the system-wide benefits of |
2 | | transportation electrification; |
3 | | (3) test innovative load management programs or rate |
4 | | structures associated with the use of electric vehicles by |
5 | | residential customers to achieve customer fuel cost |
6 | | savings relative to gasoline or diesel fuels and to |
7 | | optimize grid efficiency; |
8 | | (4) increase the integration of distributed energy |
9 | | resources in the community; |
10 | | (5) significantly expand the percentage of net-zero |
11 | | housing and net-zero buildings in the community; |
12 | | (6) improve utility bill affordability; |
13 | | (7) increase mass transit ridership; |
14 | | (8) decrease vehicle miles traveled; and |
15 | | (9) reduce local emissions of greenhouse gases, NOx, |
16 | | SOx, particulate matter, and other air pollutants. |
17 | | (e) A Community Energy and Climate Plan may be administered |
18 | | by one or more program administrators or the local unit of |
19 | | government. |
20 | | Section 15-20. Community Energy and Climate Planning |
21 | | process. |
22 | | (a) An effective planning process shall engage with a |
23 | | diverse set of stakeholders in local communities, including: |
24 | | environmental justice organizations; economic development |
25 | | organizations; faith-based nonprofit organizations; |
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1 | | educational institutions; interested residents; health care |
2 | | institutions; tenant organizations; housing institutions, |
3 | | developers, and owners; elected and appointed officials; and |
4 | | representatives reflective of each local community. |
5 | | (b) An effective planning process shall engage with |
6 | | individual members of the community as much as possible to |
7 | | ensure that the Plans receive input from as diverse set of |
8 | | perspectives as possible. |
9 | | (c) Plan materials and meetings related to the Plan shall |
10 | | be translated into languages that reflect the makeup of the |
11 | | local community. |
12 | | (d) The planning process shall be conducted in an ethical, |
13 | | transparent fashion, and will continually review its policies |
14 | | and practices to determine how best to meet its objectives.
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15 | | Section 15-25. Joint Community Energy and Climate Plans. A |
16 | | local unit of government may join with any other local unit of |
17 | | government, or with any public or private person, or with any |
18 | | number or combination thereof, under the Intergovernmental |
19 | | Cooperation Act, by contract or otherwise as may be permitted |
20 | | by law, for the implementation of a Community Energy and |
21 | | Climate Plan, in whole or in part.
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22 | | Article 20. |
23 | | Clean Energy Empowerment Zones Act |
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1 | | Section 20-1. Short title. This Article may be cited as the |
2 | | Clean Energy Empowerment Zones Act. References in this Article |
3 | | to "this Act" mean
this Article. |
4 | | Section 20-5. Legislative findings. The General Assembly |
5 | | finds that, as part of putting Illinois on path to 100% |
6 | | renewable energy, the State of Illinois should ensure a just |
7 | | transition to that goal, providing support for the transition |
8 | | of Illinois' communities and workers impacted by closures or |
9 | | reduced utilization of coal by allocating new State economic |
10 | | development resources for new business tax incentives, |
11 | | workforce training, site clean-up and reuse, and local tax |
12 | | revenue replacement.
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13 | | Section 20-10. Definitions. As used in this Act: |
14 | | "Agency" means the Illinois Environmental Protection |
15 | | Agency. |
16 | | "Department" means the Department of Commerce and Economic |
17 | | Opportunity. |
18 | | "Director" means the Director of Commerce and Economic |
19 | | Opportunity. |
20 | | "Empowerment Zones" means Clean Energy Empowerment Zones |
21 | | Program.
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22 | | "Environmental justice communities" means the proposed |
23 | | definition of that term based on existing methodologies and |
24 | | findings used by the Illinois Power Agency and its |
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1 | | Administrator in its Illinois Solar for All Program. |
2 | | Section 20-15. Clean Energy Empowerment Zones. Within 180 |
3 | | days after the effective date of this Act, the Illinois |
4 | | Department of Commerce and Economic Opportunity shall develop |
5 | | and implement strategic planning initiatives to support |
6 | | communities and workers who are economically impacted by the |
7 | | decline of fossil-fuel generation and broader changes in the |
8 | | electric sector. As part of this work, the Department shall: |
9 | | (1) work with the Illinois Environmental Protection |
10 | | Agency, Illinois Environmental Justice Commission, and the |
11 | | Illinois Department of Labor to define "Economically |
12 | | Impacted Communities and Workers" by the decline of |
13 | | fossil-fuel use; |
14 | | (2) establish funds to support impacted workers and |
15 | | communities through workforce training programs, new |
16 | | business tax incentives, and revitalization of sites |
17 | | previously used for or by those units, including, but not |
18 | | limited to, the generation sources, coal ash disposal |
19 | | sites, and areas otherwise blighted by fossil-fuel use; |
20 | | (3) convene, jointly with the Agency and at least one |
21 | | community-based organization, quarterly stakeholder |
22 | | engagement sessions beginning in the fourth quarter of 2019 |
23 | | and continuing for not less than 2 years to gather input |
24 | | from impacted community members, businesses, elected |
25 | | officials, environmental organizations, and other relevant |
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1 | | individuals or organizations on issues faced by impacted |
2 | | communities and potential economic development |
3 | | opportunities for those communities; and |
4 | | (4) provide coordination and guidance for communities |
5 | | and prospective new businesses on available workforce |
6 | | training programs, revitalization opportunities, new |
7 | | business incentives, Community Energy and Climate Plans |
8 | | under the Community Energy and Climate Planning Act, |
9 | | beneficial electrification under Section 16-107.8 of the |
10 | | Public Utilities Act, and other State and federal programs |
11 | | such as Opportunity Zones (Internal Revenue Code 1400Z). |
12 | | Article 90. |
13 | | Amendatory Provisions |
14 | | Section 90-5. The Electric Vehicle Act is amended by adding |
15 | | Sections 30, 35, and 40 as follows: |
16 | | (20 ILCS 627/30 new) |
17 | | Sec. 30. Electric Vehicle Charging Infrastructure Rebate |
18 | | and Incentive Program. |
19 | | (a) The purpose of this Section is to provide rebates and |
20 | | other incentives to residential and commercial customers to |
21 | | increase the development of electric vehicle charging |
22 | | infrastructure. |
23 | | (b) In this Section: |
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1 | | "Level 2 charging" means a charging method that allows an |
2 | | electric vehicle to be connected to permanently wired EVSE with |
3 | | a specialized connector (SAE J1772) with power levels rated at |
4 | | less than or equal to 240 VAC/80 amps. |
5 | | "Level 3 charging" means a charging method that allows an |
6 | | electric vehicle to be connected to permanently wired EVSE with |
7 | | direct current service with power levels rated at 480VAC and a |
8 | | 3-phase circuit. |
9 | | (c) Within 120 days after the effective date of this |
10 | | amendatory Act of the 101st General Assembly, the Department of |
11 | | Commerce and Economic Opportunity shall establish a program to |
12 | | provide rebates for residential customers who both install |
13 | | electric vehicle charging infrastructure on their premises and |
14 | | enroll in time-of-use, hourly rates, managed charging, or other |
15 | | beneficial electrification programs as defined in Section |
16 | | 16-107.8 of the Public Utilities Act sufficient to offset no |
17 | | less than 60% of the cost of installing that infrastructure (or |
18 | | another reasonable amount sufficient to incentivize |
19 | | development, as determined by the program administrator), |
20 | | except as provided in this subsection. |
21 | | Residential customers residing in environmental justice |
22 | | communities, as defined in the Clean Energy Empowerment Zones |
23 | | Act, or households at or below 80% of the area median income, |
24 | | who install electric vehicle charging infrastructure and |
25 | | enroll in time-of-use, hourly rates, managed charging, or other |
26 | | beneficial electrification programs as defined in Section |
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1 | | 16-107.8 of the Public Utilities Act shall be eligible to |
2 | | receive rebates of 90% of the cost of installing that |
3 | | infrastructure (or another reasonable amount sufficient to |
4 | | incentivize development, as determined by the program |
5 | | administrator). |
6 | | (d) Within 120 days after the effective date of this |
7 | | amendatory Act of the 101st General Assembly, the Department of |
8 | | Commerce and Economic Opportunity shall establish a program to |
9 | | provide rebates for Level 2 charging and Level 3 charging for |
10 | | government and commercial customers to purchase and install |
11 | | electric vehicle charging infrastructure to support |
12 | | medium-duty and heavy-duty electric fleet vehicles. Eligible |
13 | | customers must both install electric vehicle charging |
14 | | infrastructure for the purpose of charging medium-duty and |
15 | | heavy-duty electric vehicles, as defined in this subsection, |
16 | | and participate in beneficial electrification strategies as |
17 | | defined in Section 16-107.8 of the Public Utilities Act, such |
18 | | as enrolling in managed charging, installing distributed |
19 | | generation which serves all or part of the energy supply needs |
20 | | of the charging infrastructure, or other programs. The amount |
21 | | of the rebate shall be sufficient to incentivize adoption of |
22 | | electric medium-duty and heavy-duty fleet vehicles, but no less |
23 | | than 50% of the cost of purchase and installation. For the |
24 | | purposes of this Section, medium-duty and heavy-duty electric |
25 | | vehicles include school buses, transit buses, freight trucks, |
26 | | delivery vehicles, and other vehicles as defined by the program |
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1 | | administrator. |
2 | | (e) Within 120 days after the effective date of this |
3 | | amendatory Act of the 101st General Assembly, the Department of |
4 | | Commerce and Economic Opportunity shall establish a program to |
5 | | provide rebates for commercial customers to purchase and |
6 | | install charging infrastructure to support light-duty electric |
7 | | vehicles, including personal vehicles used by employees, to |
8 | | enable charging on premises. Eligible customers must both |
9 | | install electric vehicle charging infrastructure for the |
10 | | purpose of charging and participate in beneficial |
11 | | electrification strategies as defined in Section 16-107.8 of |
12 | | the Public Utilities Act, such as enrolling in Managed |
13 | | Charging, installing distributed generation which serves all |
14 | | or part of the energy supply needs of the charging |
15 | | infrastructure, or other programs. The amount of the rebate |
16 | | shall be sufficient to incentivize installation of light-duty |
17 | | electric vehicle charging infrastructure, but no less than 50% |
18 | | of the cost of purchase and installation. |
19 | | (f) Within 120 days after the effective date of this |
20 | | amendatory Act of the 101st General Assembly, the Department of |
21 | | Commerce and Economic Opportunity shall establish a program to |
22 | | provide rebates for Level 2 and Level 3 electric vehicle |
23 | | charging infrastructure which serves multi-family (three or |
24 | | more unit) residential premises. Owners of the multi-family |
25 | | property on whose premises the infrastructure will be installed |
26 | | or third parties are eligible to apply for the rebate. The |
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1 | | amount of the rebate shall be sufficient to incentivize |
2 | | installation of light-duty electric vehicle charging |
3 | | infrastructure, but no less than 50% of the cost of purchase |
4 | | and installation. |
5 | | (g) Within 120 days after the effective date of this |
6 | | amendatory Act of the 101st General Assembly, the Department of |
7 | | Commerce and Economic Opportunity shall establish a program to |
8 | | provide rebates for pilot programs which incentivize |
9 | | installation of electric vehicle charging infrastructure on |
10 | | the public way. Such programs shall include: |
11 | | (1) local governments that develop publicly-available |
12 | | electric vehicle charging using streetlights or other |
13 | | city-owned infrastructure; and |
14 | | (2) local governments and privately-owned third |
15 | | parties that install publicly-available electric vehicle |
16 | | charging infrastructure along State highways, interstates, |
17 | | and other corridors. |
18 | | (h) Within 120 days after the effective date of this |
19 | | amendatory Act of the 101st General Assembly, the Department of |
20 | | Commerce and Economic Opportunity shall establish and |
21 | | implement an Electric Vehicle Access for All Program set forth |
22 | | in Section 35. |
23 | | (i) The Department of Commerce and Economic Opportunity |
24 | | shall select, through a competitive bidding process, a program |
25 | | administrator to oversee and administer the programs described |
26 | | in this Section. |
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1 | | (j) The Department shall report to the Governor and the |
2 | | General Assembly regarding the effectiveness of the programs in |
3 | | increasing electric vehicle charging infrastructure |
4 | | development no later than July 1, 2021. |
5 | | (20 ILCS 627/35 new) |
6 | | Sec. 35. Electric Vehicle Access for All. |
7 | | (a) The General Assembly finds that it is necessary to |
8 | | provide access to electric vehicles to residents in communities |
9 | | where and for individuals whom car ownership is not an option, |
10 | | affordable, or a preference, particularly for environmental |
11 | | justice communities and low-income communities. |
12 | | (b) Within 120 days after the effective date of this |
13 | | amendatory Act of the 101st General Assembly, the Department of |
14 | | Commerce and Economic Opportunity shall establish and |
15 | | implement an Electric Vehicle Access for All Program, designed |
16 | | to maximize opportunities for carbon-free transportation |
17 | | across the State, particularly targeting environmental justice |
18 | | and low-income communities, which shall include the following |
19 | | initiatives: |
20 | | (1) Car sharing. The Department of Commerce and |
21 | | Economic Opportunity shall develop and implement an |
22 | | electric vehicle car sharing program that enables |
23 | | residents opportunities to use electric vehicles owned by |
24 | | local municipalities or other third parties for occasional |
25 | | commutes. |
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1 | | (2) Pilot programs. The Department shall dedicate |
2 | | funding for local governments' eligible Community Energy |
3 | | and Climate Plans that include Electric Vehicle Access for |
4 | | All as priority initiatives. |
5 | | (c) To the extent possible, the Department shall coordinate |
6 | | the Electric Vehicle Access for All program with the other |
7 | | programs established in this Act. |
8 | | (20 ILCS 627/40 new) |
9 | | Sec. 40. Carbon-Free Last Mile of Commutes Program. |
10 | | (a) The purpose of this Section is to provide citizens |
11 | | access to carbon-free commuting by creating pilot programs to |
12 | | address the "last mile" of commutes, enabling a larger number |
13 | | of citizens to access public transportation and reducing the |
14 | | pollution impact of the entire commute. |
15 | | (b) Within 120 days after the effective date of this |
16 | | amendatory Act of the 101st General Assembly, and for a period |
17 | | not less than 36 months thereafter, the Department of Commerce |
18 | | and Economic Opportunity shall establish and implement a Last |
19 | | Mile of Commutes Program, designed to maximize opportunities |
20 | | for carbon-free transportation across the State, particularly |
21 | | targeting environmental justice and low-income communities, to |
22 | | provide grants to pilot programs with the purpose of bridging |
23 | | public transportation gaps between residences and employment |
24 | | locations. Eligible programs may include electric shuttles, |
25 | | electric and non-electric bicycle and scooter sharing, |
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1 | | electric vehicle sharing, and other carbon-free alternatives. |
2 | | The Department of Commerce and Economic Opportunity shall |
3 | | select, through a competitive bidding program, a program |
4 | | administrator to oversee and administer the program. |
5 | | (c) In conducting the program, the Department of Commerce |
6 | | and Economic Opportunity shall partner with appropriate |
7 | | transit agencies, employers, and other transportation services |
8 | | to increase the number of employment locations reachable by |
9 | | public transit. The Department of Commerce and Economic |
10 | | Opportunity shall additionally partner with local governments |
11 | | engaging in Community Energy and Climate Planning, as described |
12 | | in the Community Energy and Climate Planning Act, to implement |
13 | | Last Mile of Commutes Programs efficiently with needs |
14 | | identified in Community Energy and Climate Plans. |
15 | | (d) The Department of Commerce and Economic Opportunity |
16 | | shall operate the Last Mile of Commutes Program in conjunction |
17 | | with the Electric Vehicle Access for All Program, to |
18 | | effectively coordinate the programs and maximize opportunities |
19 | | for carbon-free transportation across the State, particularly |
20 | | targeting environmental justice and low-income communities. |
21 | | (e) The Department of Commerce and Economic Opportunity |
22 | | shall report to the Governor and the General Assembly regarding |
23 | | the effectiveness of the programs no later than July 1, 2021. |
24 | | Section 90-10. The Illinois Power Agency Act is amended by |
25 | | changing Sections 1-5, 1-20, 1-56, and 1-75 as follows: |
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1 | | (20 ILCS 3855/1-5) |
2 | | Sec. 1-5. Legislative declarations and findings. The |
3 | | General Assembly finds and declares: |
4 | | (1) The health, welfare, and prosperity of all Illinois |
5 | | citizens require the provision of adequate, reliable, |
6 | | affordable, efficient, and environmentally sustainable |
7 | | electric service at the lowest total cost over time, taking |
8 | | into account any benefits of price stability. |
9 | | (1.5) To provide the highest quality of life for the |
10 | | residents of Illinois, and to provide for a clean and |
11 | | healthy environment, it is the policy of this State to |
12 | | rapidly transition to 100% renewable energy. |
13 | | (2) (Blank). |
14 | | (3) (Blank). |
15 | | (4) It is necessary to improve the process of procuring |
16 | | electricity to serve Illinois residents, to promote |
17 | | investment in energy efficiency and demand-response |
18 | | measures, and to maintain and support development of clean |
19 | | coal technologies, generation resources that operate at |
20 | | all hours of the day and under all weather conditions, zero |
21 | | emission facilities, and renewable resources. |
22 | | (5) Procuring a diverse electricity supply portfolio |
23 | | will ensure the lowest total cost over time for adequate, |
24 | | reliable, efficient, and environmentally sustainable |
25 | | electric service. |
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1 | | (6) Including renewable resources and zero emission |
2 | | credits from zero emission facilities in that portfolio |
3 | | will reduce long-term direct and indirect costs to |
4 | | consumers by decreasing environmental impacts and by |
5 | | avoiding or delaying the need for new generation, |
6 | | transmission, and distribution infrastructure. Developing |
7 | | new renewable energy resources in Illinois, including |
8 | | brownfield solar projects and community solar projects, |
9 | | will help to diversify Illinois electricity supply, avoid |
10 | | and reduce pollution, reduce peak demand, and enhance |
11 | | public health and well-being of Illinois residents. |
12 | | (7) Developing community solar projects in Illinois |
13 | | will help to expand access to renewable energy resources to |
14 | | more Illinois residents. |
15 | | (8) Developing brownfield solar projects in Illinois |
16 | | will help return blighted or contaminated land to |
17 | | productive use while enhancing public health and the |
18 | | well-being of Illinois residents. |
19 | | (9) Energy efficiency, demand-response measures, zero |
20 | | emission energy, and renewable energy are resources |
21 | | currently underused in Illinois. These resources should be |
22 | | used, when cost effective, to reduce costs to consumers, |
23 | | improve reliability, and improve environmental quality and |
24 | | public health. |
25 | | (10) The State should encourage the use of advanced |
26 | | clean coal technologies that capture and sequester carbon |
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1 | | dioxide emissions to advance environmental protection |
2 | | goals and to demonstrate the viability of coal and |
3 | | coal-derived fuels in a carbon-constrained economy. |
4 | | (11) The General Assembly enacted Public Act 96-0795 to |
5 | | reform the State's purchasing processes, recognizing that |
6 | | government procurement is susceptible to abuse if |
7 | | structural and procedural safeguards are not in place to |
8 | | ensure independence, insulation, oversight, and |
9 | | transparency. |
10 | | (12) The principles that underlie the procurement |
11 | | reform legislation apply also in the context of power |
12 | | purchasing. |
13 | | (13) To ensure that the benefits of installing |
14 | | renewable resources are available to all Illinois |
15 | | residents and located across the State, subject to |
16 | | appropriation, it is necessary for the Illinois Power |
17 | | Agency to provide public information and educational |
18 | | resources on how residents can benefit from the expansion |
19 | | of renewable energy in Illinois and participate in the |
20 | | Illinois Solar for All Program established in Section 1-56 |
21 | | of this Act, the Adjustable Block Program established in |
22 | | Section 1-75 of this Act, the job training programs |
23 | | established by paragraph (1) of subsection (a) of Section |
24 | | 16-108.12 of the Public Utilities Act, and the programs and |
25 | | resources established by the Clean Jobs Workforce Hubs Act. |
26 | | The General Assembly therefore finds that it is necessary |
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1 | | to create the Illinois Power Agency and that the goals and |
2 | | objectives of that Agency are to accomplish each of the |
3 | | following: |
4 | | (A) Develop electricity procurement plans to ensure |
5 | | adequate, reliable, affordable, efficient, and |
6 | | environmentally sustainable electric service at the lowest |
7 | | total cost over time, taking into account any benefits of |
8 | | price stability, for electric utilities that on December |
9 | | 31, 2005 provided electric service to at least 100,000 |
10 | | customers in Illinois and for small multi-jurisdictional |
11 | | electric utilities that (i) on December 31, 2005 served |
12 | | less than 100,000 customers in Illinois and (ii) request a |
13 | | procurement plan for their Illinois jurisdictional load. |
14 | | The procurement plan shall be updated on an annual basis |
15 | | and shall include renewable energy resources and, |
16 | | beginning with the delivery year commencing June 1, 2017, |
17 | | zero emission credits from zero emission facilities |
18 | | sufficient to achieve the standards specified in this Act. |
19 | | (B) Conduct the competitive procurement processes |
20 | | identified in this Act. |
21 | | (C) Develop electric generation and co-generation |
22 | | facilities that use indigenous coal or renewable |
23 | | resources, or both, financed with bonds issued by the |
24 | | Illinois Finance Authority. |
25 | | (D) Supply electricity from the Agency's facilities at |
26 | | cost to one or more of the following: municipal electric |
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1 | | systems, governmental aggregators, or rural electric |
2 | | cooperatives in Illinois.
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3 | | (E) Ensure that the process of power procurement is |
4 | | conducted in an ethical and transparent fashion, immune |
5 | | from improper influence. |
6 | | (F) Continue to review its policies and practices to |
7 | | determine how best to meet its mission of providing the |
8 | | lowest cost power to the greatest number of people, at any |
9 | | given point in time, in accordance with applicable law. |
10 | | (G) Operate in a structurally insulated, independent, |
11 | | and transparent fashion so that nothing impedes the |
12 | | Agency's mission to secure power at the best prices the |
13 | | market will bear, provided that the Agency meets all |
14 | | applicable legal requirements. |
15 | | (H) Implement renewable energy procurement and |
16 | | training programs throughout the State to diversify |
17 | | Illinois electricity supply, improve reliability, avoid |
18 | | and reduce pollution, reduce peak demand, and enhance |
19 | | public health and well-being of Illinois residents, |
20 | | including low-income residents. |
21 | | (Source: P.A. 99-906, eff. 6-1-17 .) |
22 | | (20 ILCS 3855/1-20) |
23 | | Sec. 1-20. General powers and duties of the Agency. |
24 | | (a) The Agency is authorized to do each of the following: |
25 | | (1) Develop electricity procurement plans to ensure |
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1 | | adequate, reliable, affordable, efficient, and |
2 | | environmentally sustainable electric service at the lowest |
3 | | total cost over time, taking into account any benefits of |
4 | | price stability, for electric utilities that on December |
5 | | 31, 2005 provided electric service to at least 100,000 |
6 | | customers in Illinois and for small multi-jurisdictional |
7 | | electric utilities that (A) on December 31, 2005 served |
8 | | less than 100,000 customers in Illinois and (B) request a |
9 | | procurement plan for their Illinois jurisdictional load. |
10 | | Except as provided in paragraph (1.5) of this subsection |
11 | | (a), the electricity procurement plans shall be updated on |
12 | | an annual basis and shall include electricity generated |
13 | | from renewable resources sufficient to achieve the |
14 | | standards specified in this Act. Beginning with the |
15 | | delivery year commencing June 1, 2017, develop procurement |
16 | | plans to include zero emission credits generated from zero |
17 | | emission facilities sufficient to achieve the standards |
18 | | specified in this Act. Beginning with the procurement for |
19 | | the delivery year commencing June 1, 2021, the Agency shall |
20 | | for each year develop a plan, as part of its procurement |
21 | | plan, to conduct a procurement of capacity from qualified |
22 | | resources needed to meet capacity requirements of the |
23 | | retail customers of electric utilities that serve more than |
24 | | 3,000,000 retail customers and are located in the PJM |
25 | | interconnection, subject to the open access tariff and |
26 | | manuals of PJM Interconnection and approved by the Federal |
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1 | | Energy Regulatory Commission. The capacity procurement |
2 | | plan shall be updated annually and shall include |
3 | | electricity generated from renewable resources sufficient |
4 | | to achieve the renewable portfolio standards as specified |
5 | | in this Act. |
6 | | (1.5) Develop a long-term renewable resources |
7 | | procurement plan in accordance with subsection (c) of |
8 | | Section 1-75 of this Act for renewable energy credits in |
9 | | amounts sufficient to achieve the standards specified in |
10 | | this Act for delivery years commencing June 1, 2017 and for |
11 | | the programs and renewable energy credits specified in |
12 | | Section 1-56 of this Act. Electricity procurement plans for |
13 | | delivery years commencing after May 31, 2017, shall not |
14 | | include procurement of renewable energy resources. |
15 | | (2) Conduct competitive procurement processes to |
16 | | procure the supply resources identified in the electricity |
17 | | procurement plan, pursuant to Section 16-111.5 of the |
18 | | Public Utilities Act, and, for the delivery year commencing |
19 | | June 1, 2017, conduct procurement processes to procure zero |
20 | | emission credits from zero emission facilities, under |
21 | | subsection (d-5) of Section 1-75 of this Act. |
22 | | (2.5) Beginning with the procurement for the 2017 |
23 | | delivery year, conduct competitive procurement processes |
24 | | and implement programs to procure renewable energy credits |
25 | | identified in the long-term renewable resources |
26 | | procurement plan developed and approved under subsection |
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1 | | (c) of Section 1-75 of this Act and Section 16-111.5 of the |
2 | | Public Utilities Act. |
3 | | (3) Develop electric generation and co-generation |
4 | | facilities that use indigenous coal or renewable |
5 | | resources, or both, financed with bonds issued by the |
6 | | Illinois Finance Authority. |
7 | | (4) Supply electricity from the Agency's facilities at |
8 | | cost to one or more of the following: municipal electric |
9 | | systems, governmental aggregators, or rural electric |
10 | | cooperatives in Illinois. |
11 | | (b) Except as otherwise limited by this Act, the Agency has |
12 | | all of the powers necessary or convenient to carry out the |
13 | | purposes and provisions of this Act, including without |
14 | | limitation, each of the following: |
15 | | (1) To have a corporate seal, and to alter that seal at |
16 | | pleasure, and to use it by causing it or a facsimile to be |
17 | | affixed or impressed or reproduced in any other manner. |
18 | | (2) To use the services of the Illinois Finance |
19 | | Authority necessary to carry out the Agency's purposes. |
20 | | (3) To negotiate and enter into loan agreements and |
21 | | other agreements with the Illinois Finance Authority. |
22 | | (4) To obtain and employ personnel and hire consultants |
23 | | that are necessary to fulfill the Agency's purposes, and to |
24 | | make expenditures for that purpose within the |
25 | | appropriations for that purpose. |
26 | | (5) To purchase, receive, take by grant, gift, devise, |
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1 | | bequest, or otherwise, lease, or otherwise acquire, own, |
2 | | hold, improve, employ, use, and otherwise deal in and with, |
3 | | real or personal property whether tangible or intangible, |
4 | | or any interest therein, within the State. |
5 | | (6) To acquire real or personal property, whether |
6 | | tangible or intangible, including without limitation |
7 | | property rights, interests in property, franchises, |
8 | | obligations, contracts, and debt and equity securities, |
9 | | and to do so by the exercise of the power of eminent domain |
10 | | in accordance with Section 1-21; except that any real |
11 | | property acquired by the exercise of the power of eminent |
12 | | domain must be located within the State. |
13 | | (7) To sell, convey, lease, exchange, transfer, |
14 | | abandon, or otherwise dispose of, or mortgage, pledge, or |
15 | | create a security interest in, any of its assets, |
16 | | properties, or any interest therein, wherever situated. |
17 | | (8) To purchase, take, receive, subscribe for, or |
18 | | otherwise acquire, hold, make a tender offer for, vote, |
19 | | employ, sell, lend, lease, exchange, transfer, or |
20 | | otherwise dispose of, mortgage, pledge, or grant a security |
21 | | interest in, use, and otherwise deal in and with, bonds and |
22 | | other obligations, shares, or other securities (or |
23 | | interests therein) issued by others, whether engaged in a |
24 | | similar or different business or activity. |
25 | | (9) To make and execute agreements, contracts, and |
26 | | other instruments necessary or convenient in the exercise |
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1 | | of the powers and functions of the Agency under this Act, |
2 | | including contracts with any person, including personal |
3 | | service contracts, or with any local government, State |
4 | | agency, or other entity; and all State agencies and all |
5 | | local governments are authorized to enter into and do all |
6 | | things necessary to perform any such agreement, contract, |
7 | | or other instrument with the Agency. No such agreement, |
8 | | contract, or other instrument shall exceed 40 years. |
9 | | (10) To lend money, invest and reinvest its funds in |
10 | | accordance with the Public Funds Investment Act, and take |
11 | | and hold real and personal property as security for the |
12 | | payment of funds loaned or invested. |
13 | | (11) To borrow money at such rate or rates of interest |
14 | | as the Agency may determine, issue its notes, bonds, or |
15 | | other obligations to evidence that indebtedness, and |
16 | | secure any of its obligations by mortgage or pledge of its |
17 | | real or personal property, machinery, equipment, |
18 | | structures, fixtures, inventories, revenues, grants, and |
19 | | other funds as provided or any interest therein, wherever |
20 | | situated. |
21 | | (12) To enter into agreements with the Illinois Finance |
22 | | Authority to issue bonds whether or not the income |
23 | | therefrom is exempt from federal taxation. |
24 | | (13) To procure insurance against any loss in |
25 | | connection with its properties or operations in such amount |
26 | | or amounts and from such insurers, including the federal |
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1 | | government, as it may deem necessary or desirable, and to |
2 | | pay any premiums therefor. |
3 | | (14) To negotiate and enter into agreements with |
4 | | trustees or receivers appointed by United States |
5 | | bankruptcy courts or federal district courts or in other |
6 | | proceedings involving adjustment of debts and authorize |
7 | | proceedings involving adjustment of debts and authorize |
8 | | legal counsel for the Agency to appear in any such |
9 | | proceedings. |
10 | | (15) To file a petition under Chapter 9 of Title 11 of |
11 | | the United States Bankruptcy Code or take other similar |
12 | | action for the adjustment of its debts. |
13 | | (16) To enter into management agreements for the |
14 | | operation of any of the property or facilities owned by the |
15 | | Agency. |
16 | | (17) To enter into an agreement to transfer and to |
17 | | transfer any land, facilities, fixtures, or equipment of |
18 | | the Agency to one or more municipal electric systems, |
19 | | governmental aggregators, or rural electric agencies or |
20 | | cooperatives, for such consideration and upon such terms as |
21 | | the Agency may determine to be in the best interest of the |
22 | | citizens of Illinois. |
23 | | (18) To enter upon any lands and within any building |
24 | | whenever in its judgment it may be necessary for the |
25 | | purpose of making surveys and examinations to accomplish |
26 | | any purpose authorized by this Act. |
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1 | | (19) To maintain an office or offices at such place or |
2 | | places in the State as it may determine. |
3 | | (20) To request information, and to make any inquiry, |
4 | | investigation, survey, or study that the Agency may deem |
5 | | necessary to enable it effectively to carry out the |
6 | | provisions of this Act. |
7 | | (21) To accept and expend appropriations. |
8 | | (22) To engage in any activity or operation that is |
9 | | incidental to and in furtherance of efficient operation to |
10 | | accomplish the Agency's purposes, including hiring |
11 | | employees that the Director deems essential for the |
12 | | operations of the Agency. |
13 | | (23) To adopt, revise, amend, and repeal rules with |
14 | | respect to its operations, properties, and facilities as |
15 | | may be necessary or convenient to carry out the purposes of |
16 | | this Act, subject to the provisions of the Illinois |
17 | | Administrative Procedure Act and Sections 1-22 and 1-35 of |
18 | | this Act. |
19 | | (24) To establish and collect charges and fees as |
20 | | described in this Act.
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21 | | (25) To conduct competitive gasification feedstock |
22 | | procurement processes to procure the feedstocks for the |
23 | | clean coal SNG brownfield facility in accordance with the |
24 | | requirements of Section 1-78 of this Act. |
25 | | (26) To review, revise, and approve sourcing |
26 | | agreements and mediate and resolve disputes between gas |
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1 | | utilities and the clean coal SNG brownfield facility |
2 | | pursuant to subsection (h-1) of Section 9-220 of the Public |
3 | | Utilities Act. |
4 | | (27) To request, review and accept proposals, execute |
5 | | contracts, purchase renewable energy credits and otherwise |
6 | | dedicate funds from the Illinois Power Agency Renewable |
7 | | Energy Resources Fund to create and carry out the |
8 | | objectives of the Illinois Solar for All program in |
9 | | accordance with Section 1-56 of this Act. |
10 | | (Source: P.A. 99-906, eff. 6-1-17 .) |
11 | | (20 ILCS 3855/1-56) |
12 | | Sec. 1-56. Illinois Power Agency Renewable Energy |
13 | | Resources Fund; Illinois Solar for All Program. |
14 | | (a) The Illinois Power Agency Renewable Energy Resources |
15 | | Fund is created as a special fund in the State treasury. |
16 | | (b) The Illinois Power Agency Renewable Energy Resources |
17 | | Fund shall be administered by the Agency as described in this |
18 | | subsection (b), provided that the changes to this subsection |
19 | | (b) made by this amendatory Act of the 99th General Assembly |
20 | | shall not interfere with existing contracts under this Section. |
21 | | (1) The Illinois Power Agency Renewable Energy |
22 | | Resources Fund shall be used to purchase renewable energy |
23 | | credits according to any approved procurement plan |
24 | | developed by the Agency prior to June 1, 2017. |
25 | | (2) The Illinois Power Agency Renewable Energy |
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1 | | Resources Fund shall also be used to create the Illinois |
2 | | Solar for All Program, which shall include incentives for |
3 | | low-income distributed generation and community solar |
4 | | projects, and other associated approved expenditures. The |
5 | | objectives of the Illinois Solar for All Program are to |
6 | | bring photovoltaics to low-income communities in this |
7 | | State in a manner that maximizes the development of new |
8 | | photovoltaic generating facilities, to create a long-term, |
9 | | low-income solar marketplace throughout this State, to |
10 | | integrate, through interaction with stakeholders, with |
11 | | existing energy efficiency initiatives, and to minimize |
12 | | administrative costs. The Agency shall include a |
13 | | description of its proposed approach to the design, |
14 | | administration, implementation and evaluation of the |
15 | | Illinois Solar for All Program, as part of the long-term |
16 | | renewable resources procurement plan authorized by |
17 | | subsection (c) of Section 1-75 of this Act, and the program |
18 | | shall be designed to grow the low-income solar market. The |
19 | | Agency or utility, as applicable, shall purchase renewable |
20 | | energy credits from the (i) photovoltaic distributed |
21 | | renewable energy generation projects and (ii) community |
22 | | solar projects that are procured under procurement |
23 | | processes authorized by the long-term renewable resources |
24 | | procurement plans approved by the Commission. |
25 | | The Illinois Solar for All Program shall include the |
26 | | program offerings described in subparagraphs (A) through |
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1 | | (D) of this paragraph (2), which the Agency shall implement |
2 | | through contracts with third-party providers and, subject |
3 | | to appropriation, pay the approximate amounts identified |
4 | | using monies available in the Illinois Power Agency |
5 | | Renewable Energy Resources Fund. Each contract that |
6 | | provides for the installation of solar facilities shall |
7 | | provide that the solar facilities will produce energy and |
8 | | economic benefits, at a level determined by the Agency to |
9 | | be reasonable, for the participating low income customers. |
10 | | The monies available in the Illinois Power Agency Renewable |
11 | | Energy Resources Fund and not otherwise committed to |
12 | | contracts executed under subsection (i) of this Section |
13 | | shall be allocated among the programs described in this |
14 | | paragraph (2), as follows: 22.5% of these funds shall be |
15 | | allocated to programs described in subparagraph (A) of this |
16 | | paragraph (2), 37.5% of these funds shall be allocated to |
17 | | programs described in subparagraph (B) of this paragraph |
18 | | (2), 15% of these funds shall be allocated to programs |
19 | | described in subparagraph (C) of this paragraph (2), and |
20 | | 25% of these funds, but in no event more than $50,000,000, |
21 | | shall be allocated to programs described in subparagraph |
22 | | (D) of this paragraph (2). Beginning with the 2019 update |
23 | | to the long-term renewable resource procurement plan |
24 | | authorized by subsection (c) of Section 1-75 of this Act, |
25 | | subject to appropriation and, following the 2021 delivery |
26 | | year, subject to fund availability through the Commission |
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1 | | process described in subparagraph (Q) of paragraph (1) of |
2 | | subsection (c) of Section 1-75, funds shall be allocated to |
3 | | programs described in subparagraphs (E) and (F) of this |
4 | | paragraph (2). The allocation of funds among subparagraphs |
5 | | (A), (B), or (C) of this paragraph (2) may be changed if |
6 | | the Agency or administrator, through delegated authority, |
7 | | determines incentives in subparagraphs (A), (B), or (C) of |
8 | | this paragraph (2) have not been adequately subscribed to |
9 | | fully utilize the Illinois Power Agency Renewable Energy |
10 | | Resources Fund. The determination shall include input |
11 | | through a stakeholder process. Additionally, if the |
12 | | Commission process described in subparagraph (Q) of |
13 | | paragraph (1) of subsection (c) of Section 1-75 results in |
14 | | an increase in funds available to the Illinois Solar for |
15 | | All program, the Agency shall reallocate the funds among |
16 | | all the various subprograms of the Illinois Solar for All |
17 | | Program to provide funding for the subprograms described in |
18 | | subparagraphs (E) and (F) of this paragraph (2). This |
19 | | reallocation shall involve input through a stakeholder |
20 | | process. The program offerings described in subparagraphs |
21 | | (A) through (D) of this paragraph (2) shall also be |
22 | | implemented through contracts funded from such additional |
23 | | amounts as are allocated to one or more of the programs in |
24 | | the long-term renewable resources procurement plans as |
25 | | specified in subsection (c) of Section 1-75 of this Act and |
26 | | subparagraph (O) of paragraph (1) of such subsection (c). |
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1 | | Contracts that will be paid with funds in the Illinois |
2 | | Power Agency Renewable Energy Resources Fund shall be |
3 | | executed by the Agency. Contracts that will be paid with |
4 | | funds collected by an electric utility shall be executed by |
5 | | the electric utility. |
6 | | Contracts under the Illinois Solar for All Program |
7 | | shall include an approach, as set forth in the long-term |
8 | | renewable resources procurement plans, to ensure the |
9 | | wholesale market value of the energy is credited to |
10 | | participating low-income customers or organizations and to |
11 | | ensure tangible economic benefits flow directly to program |
12 | | participants, except in the case of low-income |
13 | | multi-family housing where the low-income customer does |
14 | | not directly pay for energy. Priority shall be given to |
15 | | projects that demonstrate meaningful involvement of |
16 | | low-income community members in designing the initial |
17 | | proposals. Acceptable proposals to implement projects must |
18 | | demonstrate the applicant's ability to conduct initial |
19 | | community outreach, education, and recruitment of |
20 | | low-income participants in the community. Projects must |
21 | | include job training opportunities if available, and shall |
22 | | endeavor to coordinate with the job training programs |
23 | | described in paragraph (1) of subsection (a) of Section |
24 | | 16-108.12 of the Public Utilities Act. |
25 | | (A) Low-income distributed generation incentive. |
26 | | This program will provide incentives to low-income |
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1 | | customers, either directly or through solar providers, |
2 | | to increase the participation of low-income households |
3 | | in photovoltaic on-site distributed generation. |
4 | | Companies participating in this program that install |
5 | | solar panels shall commit to hiring job trainees for a |
6 | | portion of their low-income installations, and an |
7 | | administrator shall facilitate partnering the |
8 | | companies that install solar panels with entities that |
9 | | provide solar panel installation job training. It is a |
10 | | goal of this program that a minimum of 25% of the |
11 | | incentives for this program be allocated to projects |
12 | | located within environmental justice communities. |
13 | | Contracts entered into under this paragraph may be |
14 | | entered into with an entity that will develop and |
15 | | administer the program and shall also include |
16 | | contracts for renewable energy credits from the |
17 | | photovoltaic distributed generation that is the |
18 | | subject of the program, as set forth in the long-term |
19 | | renewable resources procurement plan. |
20 | | (B) Low-Income Community Solar Project Initiative. |
21 | | Incentives shall be offered to low-income customers, |
22 | | either directly or through developers, to increase the |
23 | | participation of low-income subscribers of community |
24 | | solar projects. The developer of each project shall |
25 | | identify its partnership with community stakeholders |
26 | | regarding the location, development, and participation |
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1 | | in the project, provided that nothing shall preclude a |
2 | | project from including an anchor tenant that does not |
3 | | qualify as low-income. Incentives should also be |
4 | | offered to community solar projects that are 100% |
5 | | low-income subscriber owned, which includes low-income |
6 | | households, not-for-profit organizations, and |
7 | | affordable housing owners. It is a goal of this program |
8 | | that a minimum of 25% of the incentives for this |
9 | | program be allocated to community photovoltaic |
10 | | projects in environmental justice communities. |
11 | | Contracts entered into under this paragraph may be |
12 | | entered into with developers and shall also include |
13 | | contracts for renewable energy credits related to the |
14 | | program. |
15 | | (C) Incentives for non-profits and public |
16 | | facilities. Under this program funds shall be used to |
17 | | support on-site photovoltaic distributed renewable |
18 | | energy generation devices to serve the load associated |
19 | | with not-for-profit customers and to support |
20 | | photovoltaic distributed renewable energy generation |
21 | | that uses photovoltaic technology to serve the load |
22 | | associated with public sector customers taking service |
23 | | at public buildings. It is a goal of this program that |
24 | | at least 25% of the incentives for this program be |
25 | | allocated to projects located in environmental justice |
26 | | communities. Contracts entered into under this |
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1 | | paragraph may be entered into with an entity that will |
2 | | develop and administer the program or with developers |
3 | | and shall also include contracts for renewable energy |
4 | | credits related to the program. |
5 | | (D) Low-Income Community Solar Pilot Projects. |
6 | | Under this program, persons, including, but not |
7 | | limited to, electric utilities, shall propose pilot |
8 | | community solar projects. Community solar projects |
9 | | proposed under this subparagraph (D) may exceed 2,000 |
10 | | kilowatts in nameplate capacity, but the amount paid |
11 | | per project under this program may not exceed |
12 | | $20,000,000. Pilot projects must result in economic |
13 | | benefits for the members of the community in which the |
14 | | project will be located. The proposed pilot project |
15 | | must include a partnership with at least one |
16 | | community-based organization. Approved pilot projects |
17 | | shall be competitively bid by the Agency, subject to |
18 | | fair and equitable guidelines developed by the Agency. |
19 | | Funding available under this subparagraph (D) may not |
20 | | be distributed solely to a utility, and at least some |
21 | | funds under this subparagraph (D) must include a |
22 | | project partnership that includes community ownership |
23 | | by the project subscribers. Contracts entered into |
24 | | under this paragraph may be entered into with an entity |
25 | | that will develop and administer the program or with |
26 | | developers and shall also include contracts for |
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1 | | renewable energy credits related to the program. A |
2 | | project proposed by a utility that is implemented under |
3 | | this subparagraph (D) shall not be included in the |
4 | | utility's rate base ratebase . |
5 | | (E) Energy Sovereignty Distributed Generation |
6 | | Incentive. Beginning with the 2019 update to the |
7 | | long-term renewable resource procurement plan |
8 | | authorized by subsection (c) of Section 1-75 of this |
9 | | Act, subject to appropriation, the Illinois Power |
10 | | Agency shall create a program that provides incentives |
11 | | to low-income customers, either directly or through |
12 | | solar providers, to increase the participation of |
13 | | low-income households in photovoltaic on-site |
14 | | distributed generation in projects that are 100% |
15 | | low-income household owned, which includes low-income |
16 | | households, low-income households in environmental |
17 | | justice communities, not-for-profit organizations |
18 | | providing services to low-income households, |
19 | | affordable housing owners, and community-based limited |
20 | | liability companies providing services to low-income |
21 | | households. The program shall also provide incentives |
22 | | for photovoltaic on-site distributed generation |
23 | | projects that, by no later than 5 years after the |
24 | | device is interconnected at the distribution system |
25 | | level of the utility and energized, are a minimum of |
26 | | 49% low-income subscriber owned, which includes |
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1 | | low-income households, low-income households in |
2 | | environmental justice communities, not-for-profit |
3 | | organizations providing services to low-income |
4 | | households, affordable housing owners, and |
5 | | community-based limited liability companies providing |
6 | | services to low-income households. Companies |
7 | | participating in this program that install solar |
8 | | panels shall commit to hiring job trainees for a |
9 | | portion of their low-income installations, and an |
10 | | administrator shall facilitate partnering the |
11 | | companies that install solar panels with entities that |
12 | | provide solar panel installation job training. It is a |
13 | | goal of this program that a minimum of 25% of the |
14 | | incentives for this program be allocated to projects in |
15 | | environmental justice communities. Contracts entered |
16 | | into under this paragraph may be entered into with an |
17 | | entity that will develop and administer the program and |
18 | | shall also include contracts for renewable energy |
19 | | credits from the photovoltaic distributed generation |
20 | | that is the subject of the program, as set forth in the |
21 | | long-term renewable resources procurement plan. |
22 | | (F) Energy Sovereignty Community Solar Incentive. |
23 | | Beginning with the 2019 update to the long-term |
24 | | renewable resource procurement plan authorized by |
25 | | subsection (c) of Section 1-75 of this Act, subject to |
26 | | appropriation, the Illinois Power Agency shall create |
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1 | | a program that shall provide incentives to low-income |
2 | | customers, either directly or through developers, to |
3 | | increase the participation of low-income subscribers |
4 | | of community solar projects in projects that are 100% |
5 | | low-income subscriber owned, which includes low-income |
6 | | households, low-income households in environmental |
7 | | justice communities, not-for-profit organizations |
8 | | providing services to low-income households, |
9 | | affordable housing owners, and community-based limited |
10 | | liability companies providing services to low-income |
11 | | households. The program shall also provide incentives |
12 | | for community solar projects that, by no later than 5 |
13 | | years after the device is interconnected at the |
14 | | distribution system level of the utility and |
15 | | energized, are a minimum of 49% low-income subscriber |
16 | | owned, which includes low-income households, |
17 | | low-income households in environmental justice |
18 | | communities, not-for-profit organizations providing |
19 | | services to low-income households, affordable housing |
20 | | owners, and community-based limited liability |
21 | | companies providing services to low-income households. |
22 | | The developer of each project shall identify its |
23 | | partnership with community stakeholders regarding the |
24 | | location, development and participation in the |
25 | | project. Companies participating in this program that |
26 | | install solar panels shall commit to hiring job |
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1 | | trainees for a portion of their low-income |
2 | | installations, and an administrator shall facilitate |
3 | | partnering the companies that install solar panels |
4 | | with entities that provide solar panel installation |
5 | | job training. It is a goal of this program that a |
6 | | minimum of 25% of the incentives for this program be |
7 | | allocated to projects in environmental justice |
8 | | communities. Contracts entered into under this |
9 | | paragraph may be entered into with developers and shall |
10 | | also include contracts for renewable energy credits |
11 | | related to the program. |
12 | | The requirement that a qualified person, as defined in |
13 | | paragraph (1) of subsection (i) of this Section, install |
14 | | photovoltaic devices does not apply to the Illinois Solar |
15 | | for All Program described in this subsection (b). |
16 | | (3) Costs associated with the Illinois Solar for All |
17 | | Program and its components described in paragraph (2) of |
18 | | this subsection (b), including, but not limited to, costs |
19 | | associated with procuring experts, consultants, and the |
20 | | program administrator referenced in this subsection (b) |
21 | | and related incremental costs, and costs related to the |
22 | | evaluation of the Illinois Solar for All Program, may be |
23 | | paid for using monies in the Illinois Power Agency |
24 | | Renewable Energy Resources Fund, but the Agency or program |
25 | | administrator shall strive to minimize costs in the |
26 | | implementation of the program. The Agency shall purchase |
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1 | | renewable energy credits from generation that is the |
2 | | subject of a contract under subparagraphs (A) through (D) |
3 | | of this paragraph (2) of this subsection (b), and may pay |
4 | | for such renewable energy credits through an upfront |
5 | | payment per installed kilowatt of nameplate capacity paid |
6 | | once the device is interconnected at the distribution |
7 | | system level of the utility and is energized. The payment |
8 | | shall be in exchange for an assignment of all renewable |
9 | | energy credits generated by the system during the first 15 |
10 | | years of operation and shall be structured to overcome |
11 | | barriers to participation in the solar market by the |
12 | | low-income community. The incentives provided for in this |
13 | | Section may be implemented through the pricing of renewable |
14 | | energy credits where the prices paid for the credits are |
15 | | higher than the prices from programs offered under |
16 | | subsection (c) of Section 1-75 of this Act to account for |
17 | | the incentives. The Agency shall ensure collaboration with |
18 | | community agencies, and allocate up to 5% of the funds |
19 | | available under the Illinois Solar for All Program to |
20 | | community-based groups to assist in grassroots education |
21 | | efforts related to the Illinois Solar for All Program. The |
22 | | Agency shall retire any renewable energy credits purchased |
23 | | from this program and the credits shall count towards the |
24 | | obligation under subsection (c) of Section 1-75 of this Act |
25 | | for the electric utility to which the project is |
26 | | interconnected. |
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1 | | (4) The Agency shall, consistent with the requirements |
2 | | of this subsection (b), propose the Illinois Solar for All |
3 | | Program terms, conditions, and requirements, including the |
4 | | prices to be paid for renewable energy credits, and which |
5 | | prices may be determined through a formula, through the |
6 | | development, review, and approval of the Agency's |
7 | | long-term renewable resources procurement plan described |
8 | | in subsection (c) of Section 1-75 of this Act and Section |
9 | | 16-111.5 of the Public Utilities Act. In the course of the |
10 | | Commission proceeding initiated to review and approve the |
11 | | plan, including the Illinois Solar for All Program proposed |
12 | | by the Agency, a party may propose an additional low-income |
13 | | solar or solar incentive program, or modifications to the |
14 | | programs proposed by the Agency, and the Commission may |
15 | | approve an additional program, or modifications to the |
16 | | Agency's proposed program, if the additional or modified |
17 | | program more effectively maximizes the benefits to |
18 | | low-income customers after taking into account all |
19 | | relevant factors, including, but not limited to, the extent |
20 | | to which a competitive market for low-income solar has |
21 | | developed. Following the Commission's approval of the |
22 | | Illinois Solar for All Program, the Agency or a party may |
23 | | propose adjustments to the program terms, conditions, and |
24 | | requirements, including the price offered to new systems, |
25 | | to ensure the long-term viability and success of the |
26 | | program. The Commission shall review and approve any |
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1 | | modifications to the program through the plan revision |
2 | | process described in Section 16-111.5 of the Public |
3 | | Utilities Act. |
4 | | (5) The Agency shall issue a request for qualifications |
5 | | for a third-party program administrator or administrators |
6 | | to administer all or a portion of the Illinois Solar for |
7 | | All Program. The third-party program administrator shall |
8 | | be chosen through a competitive bid process based on |
9 | | selection criteria and requirements developed by the |
10 | | Agency, including, but not limited to, experience in |
11 | | administering low-income energy programs and overseeing |
12 | | statewide clean energy or energy efficiency services. If |
13 | | the Agency retains a program administrator or |
14 | | administrators to implement all or a portion of the |
15 | | Illinois Solar for All Program, each administrator shall |
16 | | periodically submit reports to the Agency and Commission |
17 | | for each program that it administers, at appropriate |
18 | | intervals to be identified by the Agency in its long-term |
19 | | renewable resources procurement plan, provided that the |
20 | | reporting interval is at least quarterly. |
21 | | (6) The long-term renewable resources procurement plan |
22 | | shall also provide for an independent evaluation of the |
23 | | Illinois Solar for All Program. At least every 2 years, the |
24 | | Agency shall select an independent evaluator to review and |
25 | | report on the Illinois Solar for All Program and the |
26 | | performance of the third-party program administrator of |
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1 | | the Illinois Solar for All Program. The evaluation shall be |
2 | | based on objective criteria developed through a public |
3 | | stakeholder process. The process shall include feedback |
4 | | and participation from Illinois Solar for All Program |
5 | | stakeholders, including participants and organizations in |
6 | | environmental justice and historically underserved |
7 | | communities. The report shall include a summary of the |
8 | | evaluation of the Illinois Solar for All Program based on |
9 | | the stakeholder developed objective criteria. The report |
10 | | shall include the number of projects installed; the total |
11 | | installed capacity in kilowatts; the average cost per |
12 | | kilowatt of installed capacity to the extent reasonably |
13 | | obtainable by the Agency; the number of jobs or job |
14 | | opportunities created; economic, social, and environmental |
15 | | benefits created; and the total administrative costs |
16 | | expended by the Agency and program administrator to |
17 | | implement and evaluate the program. The report shall be |
18 | | delivered to the Commission and posted on the Agency's |
19 | | website, and shall be used, as needed, to revise the |
20 | | Illinois Solar for All Program. The Commission shall also |
21 | | consider the results of the evaluation as part of its |
22 | | review of the long-term renewable resources procurement |
23 | | plan under subsection (c) of Section 1-75 of this Act. |
24 | | (7) If additional funding for the programs described in |
25 | | this subsection (b) is available under subsection (k) of |
26 | | Section 16-108 of the Public Utilities Act, then the Agency |
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1 | | shall submit a procurement plan to the Commission no later |
2 | | than September 1, 2018, that proposes how the Agency will |
3 | | procure programs on behalf of the applicable utility. After |
4 | | notice and hearing, the Commission shall approve, or |
5 | | approve with modification, the plan no later than November |
6 | | 1, 2018. |
7 | | (8) Beginning with the 2019 update to the long-term |
8 | | renewable resources procurement plan authorized by |
9 | | subsection (c) of Section 1-75 of this Act, subject to |
10 | | appropriation and, following the 2021 delivery year, |
11 | | subject to fund availability through the Commission |
12 | | process described in subparagraph (Q) of paragraph (1) of |
13 | | subsection (c) of Section 1-75, the Illinois Power Agency |
14 | | shall propose an expansion of the Illinois Solar for All |
15 | | Program. The expansion shall have as a goal quadrupling the |
16 | | annual installed capacity in kilowatts under subparagraphs |
17 | | (A), (B), and (C) of paragraph (2) as well as quintupling |
18 | | the grassroots education efforts under paragraph (3) of |
19 | | this subsection. |
20 | | As used in this subsection (b), "low-income households" |
21 | | means persons and families whose income does not exceed 80% of |
22 | | area median income, adjusted for family size and revised every |
23 | | 5 years. |
24 | | For the purposes of this subsection (b), the Agency shall |
25 | | define "environmental justice community" based on |
26 | | methodologies and findings established by the Illinois Power |
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1 | | Agency and its Administrator for the Illinois Solar for All |
2 | | Program in its initial long-term renewable resources |
3 | | procurement plan and updated by the Illinois Power Agency and |
4 | | its Administrator for the Illinois Solar for All Program as |
5 | | part of the long-term renewable resources procurement plan |
6 | | update as part of long-term renewable resources procurement |
7 | | plan development, to ensure, to the extent practicable, |
8 | | compatibility with other agencies' definitions and may, for |
9 | | guidance, look to the definitions used by federal, state, or |
10 | | local governments . |
11 | | (b-5) After the receipt of all payments required by Section |
12 | | 16-115D of the Public Utilities Act, no additional funds shall |
13 | | be deposited into the Illinois Power Agency Renewable Energy |
14 | | Resources Fund unless directed by order of the Commission. |
15 | | (b-10) After the receipt of all payments required by |
16 | | Section 16-115D of the Public Utilities Act and payment in full |
17 | | of all contracts executed by the Agency under subsections (b) |
18 | | and (i) of this Section, if the balance of the Illinois Power |
19 | | Agency Renewable Energy Resources Fund is under $5,000, then |
20 | | the Fund shall be inoperative and any remaining funds and any |
21 | | funds submitted to the Fund after that date, shall be |
22 | | transferred to the Supplemental Low-Income Energy Assistance |
23 | | Fund for use in the Low-Income Home Energy Assistance Program, |
24 | | as authorized by the Energy Assistance Act. |
25 | | (c) (Blank). |
26 | | (d) (Blank). |
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1 | | (e) All renewable energy credits procured using monies from |
2 | | the Illinois Power Agency Renewable Energy Resources Fund shall |
3 | | be permanently retired. |
4 | | (f) The selection of one or more third-party program |
5 | | managers or administrators, the selection of the independent |
6 | | evaluator, and the procurement processes described in this |
7 | | Section are exempt from the requirements of the Illinois |
8 | | Procurement Code, under Section 20-10 of that Code. |
9 | | (g) All disbursements from the Illinois Power Agency |
10 | | Renewable Energy Resources Fund shall be made only upon |
11 | | warrants of the Comptroller drawn upon the Treasurer as |
12 | | custodian of the Fund upon vouchers signed by the Director or |
13 | | by the person or persons designated by the Director for that |
14 | | purpose. The Comptroller is authorized to draw the warrant upon |
15 | | vouchers so signed. The Treasurer shall accept all warrants so |
16 | | signed and shall be released from liability for all payments |
17 | | made on those warrants. |
18 | | (h) The Illinois Power Agency Renewable Energy Resources |
19 | | Fund shall not be subject to sweeps, administrative charges, or |
20 | | chargebacks, including, but not limited to, those authorized |
21 | | under Section 8h of the State Finance Act, that would in any |
22 | | way result in the transfer of any funds from this Fund to any |
23 | | other fund of this State or in having any such funds utilized |
24 | | for any purpose other than the express purposes set forth in |
25 | | this Section.
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26 | | (h-5) The Agency may assess fees to each bidder to recover |
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1 | | the costs incurred in connection with a procurement process |
2 | | held under this Section. Fees collected from bidders shall be |
3 | | deposited into the Renewable Energy Resources Fund. |
4 | | (i) Supplemental procurement process. |
5 | | (1) Within 90 days after the effective date of this |
6 | | amendatory Act of the 98th General Assembly, the Agency |
7 | | shall develop a one-time supplemental procurement plan |
8 | | limited to the procurement of renewable energy credits, if |
9 | | available, from new or existing photovoltaics, including, |
10 | | but not limited to, distributed photovoltaic generation. |
11 | | Nothing in this subsection (i) requires procurement of wind |
12 | | generation through the supplemental procurement. |
13 | | Renewable energy credits procured from new |
14 | | photovoltaics, including, but not limited to, distributed |
15 | | photovoltaic generation, under this subsection (i) must be |
16 | | procured from devices installed by a qualified person. In |
17 | | its supplemental procurement plan, the Agency shall |
18 | | establish contractually enforceable mechanisms for |
19 | | ensuring that the installation of new photovoltaics is |
20 | | performed by a qualified person. |
21 | | For the purposes of this paragraph (1), "qualified |
22 | | person" means a person who performs installations of |
23 | | photovoltaics, including, but not limited to, distributed |
24 | | photovoltaic generation, and who: (A) has completed an |
25 | | apprenticeship as a journeyman electrician from a United |
26 | | States Department of Labor registered electrical |
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1 | | apprenticeship and training program and received a |
2 | | certification of satisfactory completion; or (B) does not |
3 | | currently meet the criteria under clause (A) of this |
4 | | paragraph (1), but is enrolled in a United States |
5 | | Department of Labor registered electrical apprenticeship |
6 | | program, provided that the person is directly supervised by |
7 | | a person who meets the criteria under clause (A) of this |
8 | | paragraph (1); or (C) has obtained one of the following |
9 | | credentials in addition to attesting to satisfactory |
10 | | completion of at least 5 years or 8,000 hours of documented |
11 | | hands-on electrical experience: (i) a North American Board |
12 | | of Certified Energy Practitioners (NABCEP) Installer |
13 | | Certificate for Solar PV; (ii) an Underwriters |
14 | | Laboratories (UL) PV Systems Installer Certificate; (iii) |
15 | | an Electronics Technicians Association, International |
16 | | (ETAI) Level 3 PV Installer Certificate; or (iv) an |
17 | | Associate in Applied Science degree from an Illinois |
18 | | Community College Board approved community college program |
19 | | in renewable energy or a distributed generation |
20 | | technology. |
21 | | For the purposes of this paragraph (1), "directly |
22 | | supervised" means that there is a qualified person who |
23 | | meets the qualifications under clause (A) of this paragraph |
24 | | (1) and who is available for supervision and consultation |
25 | | regarding the work performed by persons under clause (B) of |
26 | | this paragraph (1), including a final inspection of the |
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1 | | installation work that has been directly supervised to |
2 | | ensure safety and conformity with applicable codes. |
3 | | For the purposes of this paragraph (1), "install" means |
4 | | the major activities and actions required to connect, in |
5 | | accordance with applicable building and electrical codes, |
6 | | the conductors, connectors, and all associated fittings, |
7 | | devices, power outlets, or apparatuses mounted at the |
8 | | premises that are directly involved in delivering energy to |
9 | | the premises' electrical wiring from the photovoltaics, |
10 | | including, but not limited to, to distributed photovoltaic |
11 | | generation. |
12 | | The renewable energy credits procured pursuant to the |
13 | | supplemental procurement plan shall be procured using up to |
14 | | $30,000,000 from the Illinois Power Agency Renewable |
15 | | Energy Resources Fund. The Agency shall not plan to use |
16 | | funds from the Illinois Power Agency Renewable Energy |
17 | | Resources Fund in excess of the monies on deposit in such |
18 | | fund or projected to be deposited into such fund. The |
19 | | supplemental procurement plan shall ensure adequate, |
20 | | reliable, affordable, efficient, and environmentally |
21 | | sustainable renewable energy resources (including credits) |
22 | | at the lowest total cost over time, taking into account any |
23 | | benefits of price stability. |
24 | | To the extent available, 50% of the renewable energy |
25 | | credits procured from distributed renewable energy |
26 | | generation shall come from devices of less than 25 |
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1 | | kilowatts in nameplate capacity. Procurement of renewable |
2 | | energy credits from distributed renewable energy |
3 | | generation devices shall be done through multi-year |
4 | | contracts of no less than 5 years. The Agency shall create |
5 | | credit requirements for counterparties. In order to |
6 | | minimize the administrative burden on contracting |
7 | | entities, the Agency shall solicit the use of third parties |
8 | | to aggregate distributed renewable energy. These third |
9 | | parties shall enter into and administer contracts with |
10 | | individual distributed renewable energy generation device |
11 | | owners. An individual distributed renewable energy |
12 | | generation device owner shall
have the ability to measure |
13 | | the output of his or her distributed renewable energy |
14 | | generation device. |
15 | | In developing the supplemental procurement plan, the |
16 | | Agency shall hold at least one workshop open to the public |
17 | | within 90 days after the effective date of this amendatory |
18 | | Act of the 98th General Assembly and shall consider any |
19 | | comments made by stakeholders or the public. Upon |
20 | | development of the supplemental procurement plan within |
21 | | this 90-day period, copies of the supplemental procurement |
22 | | plan shall be posted and made publicly available on the |
23 | | Agency's and Commission's websites. All interested parties |
24 | | shall have 14 days following the date of posting to provide |
25 | | comment to the Agency on the supplemental procurement plan. |
26 | | All comments submitted to the Agency shall be specific, |
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1 | | supported by data or other detailed analyses, and, if |
2 | | objecting to all or a portion of the supplemental |
3 | | procurement plan, accompanied by specific alternative |
4 | | wording or proposals. All comments shall be posted on the |
5 | | Agency's and Commission's websites. Within 14 days |
6 | | following the end of the 14-day review period, the Agency |
7 | | shall revise the supplemental procurement plan as |
8 | | necessary based on the comments received and file its |
9 | | revised supplemental procurement plan with the Commission |
10 | | for approval. |
11 | | (2) Within 5 days after the filing of the supplemental |
12 | | procurement plan at the Commission, any person objecting to |
13 | | the supplemental procurement plan shall file an objection |
14 | | with the Commission. Within 10 days after the filing, the |
15 | | Commission shall determine whether a hearing is necessary. |
16 | | The Commission shall enter its order confirming or |
17 | | modifying the supplemental procurement plan within 90 days |
18 | | after the filing of the supplemental procurement plan by |
19 | | the Agency. |
20 | | (3) The Commission shall approve the supplemental |
21 | | procurement plan of renewable energy credits to be procured |
22 | | from new or existing photovoltaics, including, but not |
23 | | limited to, distributed photovoltaic generation, if the |
24 | | Commission determines that it will ensure adequate, |
25 | | reliable, affordable, efficient, and environmentally |
26 | | sustainable electric service in the form of renewable |
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1 | | energy credits at the lowest total cost over time, taking |
2 | | into account any benefits of price stability. |
3 | | (4) The supplemental procurement process under this |
4 | | subsection (i) shall include each of the following |
5 | | components: |
6 | | (A) Procurement administrator. The Agency may |
7 | | retain a procurement administrator in the manner set |
8 | | forth in item (2) of subsection (a) of Section 1-75 of |
9 | | this Act to conduct the supplemental procurement or may |
10 | | elect to use the same procurement administrator |
11 | | administering the Agency's annual procurement under |
12 | | Section 1-75. |
13 | | (B) Procurement monitor. The procurement monitor |
14 | | retained by the Commission pursuant to Section |
15 | | 16-111.5 of the Public Utilities Act shall: |
16 | | (i) monitor interactions among the procurement |
17 | | administrator and bidders and suppliers; |
18 | | (ii) monitor and report to the Commission on |
19 | | the progress of the supplemental procurement |
20 | | process; |
21 | | (iii) provide an independent confidential |
22 | | report to the Commission regarding the results of |
23 | | the procurement events; |
24 | | (iv) assess compliance with the procurement |
25 | | plan approved by the Commission for the |
26 | | supplemental procurement process; |
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1 | | (v) preserve the confidentiality of supplier |
2 | | and bidding information in a manner consistent |
3 | | with all applicable laws, rules, regulations, and |
4 | | tariffs; |
5 | | (vi) provide expert advice to the Commission |
6 | | and consult with the procurement administrator |
7 | | regarding issues related to procurement process |
8 | | design, rules, protocols, and policy-related |
9 | | matters; |
10 | | (vii) consult with the procurement |
11 | | administrator regarding the development and use of |
12 | | benchmark criteria, standard form contracts, |
13 | | credit policies, and bid documents; and |
14 | | (viii) perform, with respect to the |
15 | | supplemental procurement process, any other |
16 | | procurement monitor duties specifically delineated |
17 | | within subsection (i) of this Section. |
18 | | (C) Solicitation, pre-qualification, and |
19 | | registration of bidders. The procurement administrator |
20 | | shall disseminate information to potential bidders to |
21 | | promote a procurement event, notify potential bidders |
22 | | that the procurement administrator may enter into a |
23 | | post-bid price negotiation with bidders that meet the |
24 | | applicable benchmarks, provide supply requirements, |
25 | | and otherwise explain the competitive procurement |
26 | | process. In addition to such other publication as the |
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1 | | procurement administrator determines is appropriate, |
2 | | this information shall be posted on the Agency's and |
3 | | the Commission's websites. The procurement |
4 | | administrator shall also administer the |
5 | | prequalification process, including evaluation of |
6 | | credit worthiness, compliance with procurement rules, |
7 | | and agreement to the standard form contract developed |
8 | | pursuant to item (D) of this paragraph (4). The |
9 | | procurement administrator shall then identify and |
10 | | register bidders to participate in the procurement |
11 | | event. |
12 | | (D) Standard contract forms and credit terms and |
13 | | instruments. The procurement administrator, in |
14 | | consultation with the Agency, the Commission, and |
15 | | other interested parties and subject to Commission |
16 | | oversight, shall develop and provide standard contract |
17 | | forms for the supplier contracts that meet generally |
18 | | accepted industry practices as well as include any |
19 | | applicable State of Illinois terms and conditions that |
20 | | are required for contracts entered into by an agency of |
21 | | the State of Illinois. Standard credit terms and |
22 | | instruments that meet generally accepted industry |
23 | | practices shall be similarly developed. Contracts for |
24 | | new photovoltaics shall include a provision attesting |
25 | | that the supplier will use a qualified person for the |
26 | | installation of the device pursuant to paragraph (1) of |
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1 | | subsection (i) of this Section. The procurement |
2 | | administrator shall make available to the Commission |
3 | | all written comments it receives on the contract forms,
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4 | | credit terms, or instruments. If the procurement |
5 | | administrator cannot reach agreement with the parties |
6 | | as to the contract terms and conditions, the |
7 | | procurement administrator must notify the Commission |
8 | | of any disputed terms and the Commission shall resolve |
9 | | the dispute. The terms of the contracts shall not be |
10 | | subject to negotiation by winning bidders, and the |
11 | | bidders must agree to the terms of the contract in |
12 | | advance so that winning bids are selected solely on the |
13 | | basis of price. |
14 | | (E) Requests for proposals; competitive |
15 | | procurement process. The procurement administrator |
16 | | shall design and issue requests for proposals to supply |
17 | | renewable energy credits in accordance with the |
18 | | supplemental procurement plan, as approved by the |
19 | | Commission. The requests for proposals shall set forth |
20 | | a procedure for sealed, binding commitment bidding |
21 | | with pay-as-bid settlement, and provision for |
22 | | selection of bids on the basis of price, provided, |
23 | | however, that no bid shall be accepted if it exceeds |
24 | | the benchmark developed pursuant to item (F) of this |
25 | | paragraph (4). |
26 | | (F) Benchmarks. Benchmarks for each product to be |
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1 | | procured shall be developed by the procurement |
2 | | administrator in consultation with Commission staff, |
3 | | the Agency, and the procurement monitor for use in this |
4 | | supplemental procurement. |
5 | | (G) A plan for implementing contingencies in the |
6 | | event of supplier default, Commission rejection of |
7 | | results, or any other cause. |
8 | | (5) Within 2 business days after opening the sealed |
9 | | bids, the procurement administrator shall submit a |
10 | | confidential report to the Commission. The report shall |
11 | | contain the results of the bidding for each of the products |
12 | | along with the procurement administrator's recommendation |
13 | | for the acceptance and rejection of bids based on the price |
14 | | benchmark criteria and other factors observed in the |
15 | | process. The procurement monitor also shall submit a |
16 | | confidential report to the Commission within 2 business |
17 | | days after opening the sealed bids. The report shall |
18 | | contain the procurement monitor's assessment of bidder |
19 | | behavior in the process as well as an assessment of the |
20 | | procurement administrator's compliance with the |
21 | | procurement process and rules. The Commission shall review |
22 | | the confidential reports submitted by the procurement |
23 | | administrator and procurement monitor and shall accept or |
24 | | reject the recommendations of the procurement |
25 | | administrator within 2 business days after receipt of the |
26 | | reports. |
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1 | | (6) Within 3 business days after the Commission |
2 | | decision approving the results of a procurement event, the |
3 | | Agency shall enter into binding contractual arrangements |
4 | | with the winning suppliers using the standard form |
5 | | contracts. |
6 | | (7) The names of the successful bidders and the average |
7 | | of the winning bid prices for each contract type and for |
8 | | each contract term shall be made available to the public |
9 | | within 2 days after the supplemental procurement event. The |
10 | | Commission, the procurement monitor, the procurement |
11 | | administrator, the Agency, and all participants in the |
12 | | procurement process shall maintain the confidentiality of |
13 | | all other supplier and bidding information in a manner |
14 | | consistent with all applicable laws, rules, regulations, |
15 | | and tariffs. Confidential information, including the |
16 | | confidential reports submitted by the procurement |
17 | | administrator and procurement monitor pursuant to this |
18 | | Section, shall not be made publicly available and shall not |
19 | | be discoverable by any party in any proceeding, absent a |
20 | | compelling demonstration of need, nor shall those reports |
21 | | be admissible in any proceeding other than one for law |
22 | | enforcement purposes. |
23 | | (8) The supplemental procurement provided in this |
24 | | subsection (i) shall not be subject to the requirements and |
25 | | limitations of subsections (c) and (d) of this Section. |
26 | | (9) Expenses incurred in connection with the |
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1 | | procurement process held pursuant to this Section, |
2 | | including, but not limited to, the cost of developing the |
3 | | supplemental procurement plan, the procurement |
4 | | administrator, procurement monitor, and the cost of the |
5 | | retirement of renewable energy credits purchased pursuant |
6 | | to the supplemental procurement shall be paid for from the |
7 | | Illinois Power Agency Renewable Energy Resources Fund. The |
8 | | Agency shall enter into an interagency agreement with the |
9 | | Commission to reimburse the Commission for its costs |
10 | | associated with the procurement monitor for the |
11 | | supplemental procurement process. |
12 | | (Source: P.A. 98-672, eff. 6-30-14; 99-906, eff. 6-1-17 .) |
13 | | (20 ILCS 3855/1-75) |
14 | | Sec. 1-75. Planning and Procurement Bureau. The Planning |
15 | | and Procurement Bureau has the following duties and |
16 | | responsibilities: |
17 | | (a) The Planning and Procurement Bureau shall each year, |
18 | | beginning in 2008, develop procurement plans and conduct |
19 | | competitive procurement processes in accordance with the |
20 | | requirements of Section 16-111.5 of the Public Utilities Act |
21 | | for the eligible retail customers of electric utilities that on |
22 | | December 31, 2005 provided electric service to at least 100,000 |
23 | | customers in Illinois. Beginning with the delivery year |
24 | | commencing on June 1, 2017, the Planning and Procurement Bureau |
25 | | shall develop plans and processes for the procurement of zero |
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1 | | emission credits from zero emission facilities in accordance |
2 | | with the requirements of subsection (d-5) of this Section. The |
3 | | Planning and Procurement Bureau shall also develop procurement |
4 | | plans and conduct competitive procurement processes in |
5 | | accordance with the requirements of Section 16-111.5 of the |
6 | | Public Utilities Act for the eligible retail customers of small |
7 | | multi-jurisdictional electric utilities that (i) on December |
8 | | 31, 2005 served less than 100,000 customers in Illinois and |
9 | | (ii) request a procurement plan for their Illinois |
10 | | jurisdictional load. This Section shall not apply to a small |
11 | | multi-jurisdictional utility until such time as a small |
12 | | multi-jurisdictional utility requests the Agency to prepare a |
13 | | procurement plan for their Illinois jurisdictional load. For |
14 | | the purposes of this Section, the term "eligible retail |
15 | | customers" has the same definition as found in Section |
16 | | 16-111.5(a) of the Public Utilities Act. |
17 | | Beginning with the plan or plans to be implemented in the |
18 | | 2017 delivery year, the Agency shall no longer include the |
19 | | procurement of renewable energy resources in the annual |
20 | | procurement plans required by this subsection (a), except as |
21 | | provided in subsection (q) of Section 16-111.5 of the Public |
22 | | Utilities Act and subsection (j) of this Section , and shall |
23 | | instead develop a long-term renewable resources procurement |
24 | | plan in accordance with subsection (c) of this Section and |
25 | | Section 16-111.5 of the Public Utilities Act. |
26 | | (1) The Agency shall each year, beginning in 2008, as |
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1 | | needed, issue a request for qualifications for experts or |
2 | | expert consulting firms to develop the procurement plans in |
3 | | accordance with Section 16-111.5 of the Public Utilities |
4 | | Act. In order to qualify an expert or expert consulting |
5 | | firm must have: |
6 | | (A) direct previous experience assembling |
7 | | large-scale power supply plans or portfolios for |
8 | | end-use customers; |
9 | | (B) an advanced degree in economics, mathematics, |
10 | | engineering, risk management, or a related area of |
11 | | study; |
12 | | (C) 10 years of experience in the electricity |
13 | | sector, including managing supply risk; |
14 | | (D) expertise in wholesale electricity market |
15 | | rules, including those established by the Federal |
16 | | Energy Regulatory Commission and regional transmission |
17 | | organizations; |
18 | | (E) expertise in credit protocols and familiarity |
19 | | with contract protocols; |
20 | | (F) adequate resources to perform and fulfill the |
21 | | required functions and responsibilities; and |
22 | | (G) the absence of a conflict of interest and |
23 | | inappropriate bias for or against potential bidders or |
24 | | the affected electric utilities. |
25 | | (2) The Agency shall each year, as needed, issue a |
26 | | request for qualifications for a procurement administrator |
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1 | | to conduct the competitive procurement processes in |
2 | | accordance with Section 16-111.5 of the Public Utilities |
3 | | Act. In order to qualify an expert or expert consulting |
4 | | firm must have: |
5 | | (A) direct previous experience administering a |
6 | | large-scale competitive procurement process; |
7 | | (B) an advanced degree in economics, mathematics, |
8 | | engineering, or a related area of study; |
9 | | (C) 10 years of experience in the electricity |
10 | | sector, including risk management experience; |
11 | | (D) expertise in wholesale electricity market |
12 | | rules, including those established by the Federal |
13 | | Energy Regulatory Commission and regional transmission |
14 | | organizations; |
15 | | (E) expertise in credit and contract protocols; |
16 | | (F) adequate resources to perform and fulfill the |
17 | | required functions and responsibilities; and |
18 | | (G) the absence of a conflict of interest and |
19 | | inappropriate bias for or against potential bidders or |
20 | | the affected electric utilities. |
21 | | (3) The Agency shall provide affected utilities and |
22 | | other interested parties with the lists of qualified |
23 | | experts or expert consulting firms identified through the |
24 | | request for qualifications processes that are under |
25 | | consideration to develop the procurement plans and to serve |
26 | | as the procurement administrator. The Agency shall also |
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1 | | provide each qualified expert's or expert consulting |
2 | | firm's response to the request for qualifications. All |
3 | | information provided under this subparagraph shall also be |
4 | | provided to the Commission. The Agency may provide by rule |
5 | | for fees associated with supplying the information to |
6 | | utilities and other interested parties. These parties |
7 | | shall, within 5 business days, notify the Agency in writing |
8 | | if they object to any experts or expert consulting firms on |
9 | | the lists. Objections shall be based on: |
10 | | (A) failure to satisfy qualification criteria; |
11 | | (B) identification of a conflict of interest; or |
12 | | (C) evidence of inappropriate bias for or against |
13 | | potential bidders or the affected utilities. |
14 | | The Agency shall remove experts or expert consulting |
15 | | firms from the lists within 10 days if there is a |
16 | | reasonable basis for an objection and provide the updated |
17 | | lists to the affected utilities and other interested |
18 | | parties. If the Agency fails to remove an expert or expert |
19 | | consulting firm from a list, an objecting party may seek |
20 | | review by the Commission within 5 days thereafter by filing |
21 | | a petition, and the Commission shall render a ruling on the |
22 | | petition within 10 days. There is no right of appeal of the |
23 | | Commission's ruling. |
24 | | (4) The Agency shall issue requests for proposals to |
25 | | the qualified experts or expert consulting firms to develop |
26 | | a procurement plan for the affected utilities and to serve |
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1 | | as procurement administrator. |
2 | | (5) The Agency shall select an expert or expert |
3 | | consulting firm to develop procurement plans based on the |
4 | | proposals submitted and shall award contracts of up to 5 |
5 | | years to those selected. |
6 | | (6) The Agency shall select an expert or expert |
7 | | consulting firm, with approval of the Commission, to serve |
8 | | as procurement administrator based on the proposals |
9 | | submitted. If the Commission rejects, within 5 days, the |
10 | | Agency's selection, the Agency shall submit another |
11 | | recommendation within 3 days based on the proposals |
12 | | submitted. The Agency shall award a 5-year contract to the |
13 | | expert or expert consulting firm so selected with |
14 | | Commission approval. |
15 | | (b) The experts or expert consulting firms retained by the |
16 | | Agency shall, as appropriate, prepare procurement plans, and |
17 | | conduct a competitive procurement process as prescribed in |
18 | | Section 16-111.5 of the Public Utilities Act, to ensure |
19 | | adequate, reliable, affordable, efficient, and environmentally |
20 | | sustainable electric service at the lowest total cost over |
21 | | time, taking into account any benefits of price stability, for |
22 | | eligible retail customers of electric utilities that on |
23 | | December 31, 2005 provided electric service to at least 100,000 |
24 | | customers in the State of Illinois, and for eligible Illinois |
25 | | retail customers of small multi-jurisdictional electric |
26 | | utilities that (i) on December 31, 2005 served less than |
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1 | | 100,000 customers in Illinois and (ii) request a procurement |
2 | | plan for their Illinois jurisdictional load. |
3 | | (c) Renewable portfolio standard. |
4 | | (1)(A) The Agency shall develop a long-term renewable |
5 | | resources procurement plan that shall include procurement |
6 | | programs and competitive procurement events necessary to |
7 | | meet the goals set forth in this subsection (c). The |
8 | | initial long-term renewable resources procurement plan |
9 | | shall be released for comment no later than 160 days after |
10 | | June 1, 2017 (the effective date of Public Act 99-906). The |
11 | | Agency shall review, and may revise on an expedited basis, |
12 | | the long-term renewable resources procurement plan at |
13 | | least every 2 years, which shall be conducted in |
14 | | conjunction with the procurement plan under Section |
15 | | 16-111.5 of the Public Utilities Act to the extent |
16 | | practicable to minimize administrative expense. The |
17 | | long-term renewable resources procurement plans shall be |
18 | | subject to review and approval by the Commission under |
19 | | Section 16-111.5 of the Public Utilities Act. |
20 | | (B) Subject to subparagraph (F) of this paragraph (1), |
21 | | the long-term renewable resources procurement plan shall |
22 | | include the goals for procurement of renewable energy |
23 | | credits to meet at least the following overall percentages: |
24 | | 13% by the 2017 delivery year; increasing by at least 1.5% |
25 | | each delivery year thereafter to at least 25% by the 2025 |
26 | | delivery year; increasing by at least 4% each delivery year |
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1 | | after the 2025 delivery year to at least 45% by 2030; |
2 | | increasing by at least 3% each delivery year after the 2030 |
3 | | delivery year to at least 60% by 2035, 75% by 2040, and 90% |
4 | | by 2045; increasing by at least 2% each delivery year after |
5 | | the 2045 delivery year to 100% by the 2050 delivery year |
6 | | and continuing at 100% no less than 25% for each delivery |
7 | | year thereafter. In the event of a conflict between these |
8 | | goals and the new wind and new photovoltaic procurement |
9 | | requirements described in items (i) through (iii) of |
10 | | subparagraph (C) and items (i) and (ii) of subparagraph (P) |
11 | | of this paragraph (1), the long-term plan shall prioritize |
12 | | compliance with the new wind and new photovoltaic |
13 | | procurement requirements described in items (i) through |
14 | | (iii) of subparagraph (C) and items (i) and (ii) of |
15 | | subparagraph (P) of this paragraph (1) over the annual |
16 | | percentage targets described in this subparagraph (B). The |
17 | | Agency shall not comply with the annual percentage targets |
18 | | described in this subparagraph (B) by procuring renewable |
19 | | energy credits on the spot market that are unlikely to lead |
20 | | to the development of new renewable resources. |
21 | | For the delivery year beginning June 1, 2017, the |
22 | | procurement plan shall include cost-effective renewable |
23 | | energy resources equal to at least 13% of each utility's |
24 | | load for eligible retail customers and 13% of the |
25 | | applicable portion of each utility's load for retail |
26 | | customers who are not eligible retail customers, which |
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1 | | applicable portion shall equal 50% of the utility's load |
2 | | for retail customers who are not eligible retail customers |
3 | | on February 28, 2017. |
4 | | For the delivery year beginning June 1, 2018, the |
5 | | procurement plan shall include cost-effective renewable |
6 | | energy resources equal to at least 14.5% of each utility's |
7 | | load for eligible retail customers and 14.5% of the |
8 | | applicable portion of each utility's load for retail |
9 | | customers who are not eligible retail customers, which |
10 | | applicable portion shall equal 75% of the utility's load |
11 | | for retail customers who are not eligible retail customers |
12 | | on February 28, 2017. |
13 | | For the delivery year beginning June 1, 2019, and for |
14 | | each year thereafter, the procurement plans shall include |
15 | | cost-effective renewable energy resources equal to a |
16 | | minimum percentage of each utility's load for all retail |
17 | | customers as follows: 16% by June 1, 2019; increasing by |
18 | | 1.5% each year thereafter to 25% by June 1, 2025; |
19 | | increasing by at least 4% each year thereafter to at least |
20 | | 45% by June 1, 2030; increasing by at least 3% each year |
21 | | thereafter to at least 90% by June 1, 2045; increasing by |
22 | | at least 2% each year thereafter to at least 100% by June |
23 | | 1, 2050 and 25% by June 1, 2026 and each year thereafter. |
24 | | For each delivery year, the Agency shall first |
25 | | recognize each utility's obligations for that delivery |
26 | | year under existing contracts. Any renewable energy |
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1 | | credits under existing contracts, including renewable |
2 | | energy credits as part of renewable energy resources, shall |
3 | | be used to meet the goals set forth in this subsection (c) |
4 | | for the delivery year. |
5 | | (C) Of the renewable energy credits procured under this |
6 | | subsection (c), at least 75% shall come from wind and |
7 | | photovoltaic projects. The long-term renewable resources |
8 | | procurement plan described in subparagraph (A) of this |
9 | | paragraph (1) shall include the procurement of renewable |
10 | | energy credits in amounts equal to at least the following: |
11 | | (i) By the end of the 2020 delivery year: |
12 | | At least 2,000,000 renewable energy credits |
13 | | for each delivery year shall come from new wind |
14 | | projects; and |
15 | | At least 2,000,000 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 | | generation devices or community renewable |
23 | | generation projects; at least 40% from |
24 | | utility-scale solar projects; at least 2% from |
25 | | brownfield site photovoltaic projects that are not |
26 | | community renewable generation projects; and the |
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1 | | remainder shall be determined through the |
2 | | long-term planning process described in |
3 | | subparagraph (A) of this paragraph (1). |
4 | | (ii) By the end of the 2025 delivery year: |
5 | | At least 3,000,000 renewable energy credits |
6 | | for each delivery year shall come from new wind |
7 | | projects; and |
8 | | At least 3,000,000 renewable energy credits |
9 | | for each delivery year shall come from new |
10 | | photovoltaic projects; of that amount, to the |
11 | | extent possible, the Agency shall procure: at |
12 | | least 50% from solar photovoltaic projects using |
13 | | the program outlined in subparagraph (K) of this |
14 | | paragraph (1) from distributed renewable energy |
15 | | devices or community renewable generation |
16 | | projects; at least 40% from utility-scale solar |
17 | | projects; at least 2% from brownfield site |
18 | | photovoltaic projects that are not community |
19 | | renewable generation projects; and the remainder |
20 | | shall be determined through the long-term planning |
21 | | process described in subparagraph (A) of this |
22 | | paragraph (1). |
23 | | (iii) By the end of the 2030 delivery year: |
24 | | At least 4,000,000 renewable energy credits |
25 | | for each delivery year shall come from new wind |
26 | | projects; and |
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1 | | At least 4,000,000 renewable energy credits |
2 | | for each delivery year shall come from new |
3 | | photovoltaic projects; of that amount, to the |
4 | | extent possible, the Agency shall procure: at |
5 | | least 50% from solar photovoltaic projects using |
6 | | the program outlined in subparagraph (K) of this |
7 | | paragraph (1) from distributed renewable energy |
8 | | devices or community renewable generation |
9 | | projects; at least 40% from utility-scale solar |
10 | | projects; at least 2% from brownfield site |
11 | | photovoltaic projects that are not community |
12 | | renewable generation projects; and the remainder |
13 | | shall be determined through the long-term planning |
14 | | process described in subparagraph (A) of this |
15 | | paragraph (1). |
16 | | For purposes of this Section: |
17 | | "New wind projects" means wind renewable |
18 | | energy facilities that are energized after June 1, |
19 | | 2017 for the delivery year commencing June 1, 2017 |
20 | | or within 3 years after the date the Commission |
21 | | approves contracts for subsequent delivery years. |
22 | | "New photovoltaic projects" means photovoltaic |
23 | | renewable energy facilities that are energized |
24 | | after June 1, 2017. Photovoltaic projects |
25 | | developed under Section 1-56 of this Act shall not |
26 | | apply towards the new photovoltaic project |
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1 | | requirements in this subparagraph (C). |
2 | | (D) Renewable energy credits shall be cost effective. |
3 | | For purposes of this subsection (c), "cost effective" means |
4 | | that the costs of procuring renewable energy resources do |
5 | | not cause the limit stated in subparagraph (E) of this |
6 | | paragraph (1) to be exceeded and, for renewable energy |
7 | | credits procured through a competitive procurement event, |
8 | | do not exceed benchmarks based on market prices for like |
9 | | products in the region. For purposes of this subsection |
10 | | (c), "like products" means contracts for renewable energy |
11 | | credits from the same or substantially similar technology, |
12 | | same or substantially similar vintage (new or existing), |
13 | | the same or substantially similar quantity, and the same or |
14 | | substantially similar contract length and structure. |
15 | | Benchmarks shall be developed by the procurement |
16 | | administrator, in consultation with the Commission staff, |
17 | | Agency staff, and the procurement monitor and shall be |
18 | | subject to Commission review and approval. If price |
19 | | benchmarks for like products in the region are not |
20 | | available, the procurement administrator shall establish |
21 | | price benchmarks based on publicly available data on |
22 | | regional technology costs and expected current and future |
23 | | regional energy prices. The benchmarks in this Section |
24 | | shall not be used to curtail or otherwise reduce |
25 | | contractual obligations entered into by or through the |
26 | | Agency prior to June 1, 2017 (the effective date of Public |
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1 | | Act 99-906). |
2 | | (E) For purposes of this subsection (c), the required |
3 | | procurement of cost-effective renewable energy resources |
4 | | for a particular year commencing prior to June 1, 2017 |
5 | | shall be measured as a percentage of the actual amount of |
6 | | electricity (megawatt-hours) supplied by the electric |
7 | | utility to eligible retail customers in the delivery year |
8 | | ending immediately prior to the procurement, and, for |
9 | | delivery years commencing on and after June 1, 2017, the |
10 | | required procurement of cost-effective renewable energy |
11 | | resources for a particular year shall be measured as a |
12 | | percentage of the actual amount of electricity |
13 | | (megawatt-hours) delivered by the electric utility in the |
14 | | delivery year ending immediately prior to the procurement, |
15 | | to all retail customers in its service territory. For |
16 | | purposes of this subsection (c), the amount paid per |
17 | | kilowatthour means the total amount paid for electric |
18 | | service expressed on a per kilowatthour basis. For purposes |
19 | | of this subsection (c), the total amount paid for electric |
20 | | service includes without limitation amounts paid for |
21 | | supply, transmission, distribution, surcharges, and add-on |
22 | | taxes. |
23 | | Notwithstanding the requirements of this subsection |
24 | | (c), the total of renewable energy resources procured under |
25 | | the procurement plan for any single year shall be subject |
26 | | to the limitations of this subparagraph (E). Such |
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1 | | procurement shall be reduced for all retail customers based |
2 | | on the amount necessary to limit the annual estimated |
3 | | average net increase due to the costs of these resources |
4 | | included in the amounts paid by eligible retail customers |
5 | | in connection with electric service to no more than the |
6 | | greater of 2.015% of the amount paid per kilowatthour by |
7 | | those customers during the year ending May 31, 2007 or the |
8 | | incremental amount per kilowatthour paid for these |
9 | | resources in 2011. To arrive at a maximum dollar amount of |
10 | | renewable energy resources to be procured for the |
11 | | particular delivery year, the resulting per kilowatthour |
12 | | amount shall be applied to the actual amount of |
13 | | kilowatthours of electricity delivered, or applicable |
14 | | portion of such amount as specified in paragraph (1) of |
15 | | this subsection (c), as applicable, by the electric utility |
16 | | in the delivery year immediately prior to the procurement |
17 | | to all retail customers in its service territory. The |
18 | | calculations required by this subparagraph (E) shall be |
19 | | made only once for each delivery year at the time that the |
20 | | renewable energy resources are procured. Once the |
21 | | determination as to the amount of renewable energy |
22 | | resources to procure is made based on the calculations set |
23 | | forth in this subparagraph (E) and the contracts procuring |
24 | | those amounts are executed, no subsequent rate impact |
25 | | determinations shall be made and no adjustments to those |
26 | | contract amounts shall be allowed. All costs incurred under |
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1 | | such contracts shall be fully recoverable by the electric |
2 | | utility as provided in this Section. |
3 | | (F) If the limitation on the amount of renewable energy |
4 | | resources procured in subparagraph (E) of this paragraph |
5 | | (1) prevents the Agency from meeting all of the goals in |
6 | | this subsection (c), the Agency's long-term plan shall |
7 | | prioritize compliance with the requirements of this |
8 | | subsection (c) regarding renewable energy credits in the |
9 | | following order: |
10 | | (i) renewable energy credits under existing |
11 | | contractual obligations; |
12 | | (i-5) funding for the Illinois Solar for All |
13 | | Program, as described in subparagraph (O) of this |
14 | | paragraph (1); |
15 | | (ii) renewable energy credits necessary to comply |
16 | | with the new wind and new photovoltaic procurement |
17 | | requirements described in items (i) through (iii) of |
18 | | subparagraph (C) of this paragraph (1); and |
19 | | (ii-5) renewable energy credits necessary to |
20 | | comply with the new wind and new photovoltaic |
21 | | procurement requirements described in subparagraph (P) |
22 | | of this paragraph (1); and |
23 | | (iii) renewable energy credits necessary to meet |
24 | | the remaining requirements of this subsection (c). |
25 | | (G) The following provisions shall apply to the |
26 | | Agency's procurement of renewable energy credits under |
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1 | | this subsection (c): |
2 | | (i) Notwithstanding whether a long-term renewable |
3 | | resources procurement plan has been approved, the |
4 | | Agency shall conduct an initial forward procurement |
5 | | for renewable energy credits from new utility-scale |
6 | | wind projects within 160 days after June 1, 2017 (the |
7 | | effective date of Public Act 99-906). For the purposes |
8 | | of this initial forward procurement, the Agency shall |
9 | | solicit 15-year contracts for delivery of 1,000,000 |
10 | | renewable energy credits delivered annually from new |
11 | | utility-scale wind projects to begin delivery on June |
12 | | 1, 2019, if available, but not later than June 1, 2021. |
13 | | Payments to suppliers of renewable energy credits |
14 | | shall commence upon delivery. Renewable energy credits |
15 | | procured under this initial procurement shall be |
16 | | included in the Agency's long-term plan and shall apply |
17 | | to all renewable energy goals in this subsection (c). |
18 | | (ii) Notwithstanding whether a long-term renewable |
19 | | resources procurement plan has been approved, the |
20 | | Agency shall conduct an initial forward procurement |
21 | | for renewable energy credits from new utility-scale |
22 | | solar projects and brownfield site photovoltaic |
23 | | projects within one year after June 1, 2017 (the |
24 | | effective date of Public Act 99-906). For the purposes |
25 | | of this initial forward procurement, the Agency shall |
26 | | solicit 15-year contracts for delivery of 1,000,000 |
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1 | | renewable energy credits delivered annually from new |
2 | | utility-scale solar projects and brownfield site |
3 | | photovoltaic projects to begin delivery on June 1, |
4 | | 2019, if available, but not later than June 1, 2021. |
5 | | The Agency may structure this initial procurement in |
6 | | one or more discrete procurement events. Payments to |
7 | | suppliers of renewable energy credits shall commence |
8 | | upon delivery. Renewable energy credits procured under |
9 | | this initial procurement shall be included in the |
10 | | Agency's long-term plan and shall apply to all |
11 | | renewable energy goals in this subsection (c). |
12 | | (iii) Subsequent forward procurements for |
13 | | utility-scale wind projects shall solicit at least |
14 | | 1,000,000 renewable energy credits delivered annually |
15 | | per procurement event and shall be planned, scheduled, |
16 | | and designed such that the cumulative amount of |
17 | | renewable energy credits delivered from all new wind |
18 | | projects in each delivery year shall not exceed the |
19 | | Agency's projection of the cumulative amount of |
20 | | renewable energy credits that will be delivered from |
21 | | all new photovoltaic projects, including utility-scale |
22 | | and distributed photovoltaic devices, in the same |
23 | | delivery year at the time scheduled for wind contract |
24 | | delivery. |
25 | | (iv) If, at any time after the time set for |
26 | | delivery of renewable energy credits pursuant to the |
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1 | | initial procurements in items (i) and (ii) of this |
2 | | subparagraph (G), the cumulative amount of renewable |
3 | | energy credits projected to be delivered from all new |
4 | | wind projects in a given delivery year exceeds the |
5 | | cumulative amount of renewable energy credits |
6 | | projected to be delivered from all new photovoltaic |
7 | | projects in that delivery year by 200,000 or more |
8 | | renewable energy credits, then the Agency shall within |
9 | | 60 days adjust the procurement programs in the |
10 | | long-term renewable resources procurement plan to |
11 | | ensure that the projected cumulative amount of |
12 | | renewable energy credits to be delivered from all new |
13 | | wind projects does not exceed the projected cumulative |
14 | | amount of renewable energy credits to be delivered from |
15 | | all new photovoltaic projects by 200,000 or more |
16 | | renewable energy credits, provided that nothing in |
17 | | this Section shall preclude the projected cumulative |
18 | | amount of renewable energy credits to be delivered from |
19 | | all new photovoltaic projects from exceeding the |
20 | | projected cumulative amount of renewable energy |
21 | | credits to be delivered from all new wind projects in |
22 | | each delivery year and provided further that nothing in |
23 | | this item (iv) shall require the curtailment of an |
24 | | executed contract. The Agency shall update, on a |
25 | | quarterly basis, its projection of the renewable |
26 | | energy credits to be delivered from all projects in |
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1 | | each delivery year. Notwithstanding anything to the |
2 | | contrary, the Agency may adjust the timing of |
3 | | procurement events conducted under this subparagraph |
4 | | (G). The long-term renewable resources procurement |
5 | | plan shall set forth the process by which the |
6 | | adjustments may be made. |
7 | | (v) All procurements under this subparagraph (G) |
8 | | shall comply with the geographic requirements in |
9 | | subparagraph (I) of this paragraph (1) and shall follow |
10 | | the procurement processes and procedures described in |
11 | | this Section and Section 16-111.5 of the Public |
12 | | Utilities Act to the extent practicable, and these |
13 | | processes and procedures may be expedited to |
14 | | accommodate the schedule established by this |
15 | | subparagraph (G). |
16 | | (H) The procurement of renewable energy resources for a |
17 | | given delivery year shall be reduced as described in this |
18 | | subparagraph (H) if an alternative retail electric |
19 | | supplier meets the requirements described in this |
20 | | subparagraph (H). |
21 | | (i) Within 45 days after June 1, 2017 (the |
22 | | effective date of Public Act 99-906), an alternative |
23 | | retail electric supplier or its successor shall submit |
24 | | an informational filing to the Illinois Commerce |
25 | | Commission certifying that, as of December 31, 2015, |
26 | | the alternative retail electric supplier owned one or |
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1 | | more electric generating facilities that generates |
2 | | renewable energy resources as defined in Section 1-10 |
3 | | of this Act, provided that such facilities are not |
4 | | powered by wind or photovoltaics, and the facilities |
5 | | generate one renewable energy credit for each |
6 | | megawatthour of energy produced from the facility. |
7 | | The informational filing shall identify each |
8 | | facility that was eligible to satisfy the alternative |
9 | | retail electric supplier's obligations under Section |
10 | | 16-115D of the Public Utilities Act as described in |
11 | | this item (i). |
12 | | (ii) For a given delivery year, the alternative |
13 | | retail electric supplier may elect to supply its retail |
14 | | customers with renewable energy credits from the |
15 | | facility or facilities described in item (i) of this |
16 | | subparagraph (H) that continue to be owned by the |
17 | | alternative retail electric supplier. |
18 | | (iii) The alternative retail electric supplier |
19 | | shall notify the Agency and the applicable utility, no |
20 | | later than February 28 of the year preceding the |
21 | | applicable delivery year or 15 days after June 1, 2017 |
22 | | (the effective date of Public Act 99-906), whichever is |
23 | | later, of its election under item (ii) of this |
24 | | subparagraph (H) to supply renewable energy credits to |
25 | | retail customers of the utility. Such election shall |
26 | | identify the amount of renewable energy credits to be |
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1 | | supplied by the alternative retail electric supplier |
2 | | to the utility's retail customers and the source of the |
3 | | renewable energy credits identified in the |
4 | | informational filing as described in item (i) of this |
5 | | subparagraph (H), subject to the following |
6 | | limitations: |
7 | | For the delivery year beginning June 1, 2018, |
8 | | the maximum amount of renewable energy credits to |
9 | | be supplied by an alternative retail electric |
10 | | supplier under this subparagraph (H) shall be 68% |
11 | | multiplied by 25% multiplied by 14.5% multiplied |
12 | | by the amount of metered electricity |
13 | | (megawatt-hours) delivered by the alternative |
14 | | retail electric supplier to Illinois retail |
15 | | customers during the delivery year ending May 31, |
16 | | 2016. |
17 | | For delivery years beginning June 1, 2019 and |
18 | | each year thereafter, the maximum amount of |
19 | | renewable energy credits to be supplied by an |
20 | | alternative retail electric supplier under this |
21 | | subparagraph (H) shall be 68% multiplied by 50% |
22 | | multiplied by 16% multiplied by the amount of |
23 | | metered electricity (megawatt-hours) delivered by |
24 | | the alternative retail electric supplier to |
25 | | Illinois retail customers during the delivery year |
26 | | ending May 31, 2016, provided that the 16% value |
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1 | | shall increase by 1.5% each delivery year |
2 | | thereafter to 25% by the delivery year beginning |
3 | | June 1, 2025, and thereafter the 25% value shall |
4 | | apply to each delivery year. |
5 | | For each delivery year, the total amount of |
6 | | renewable energy credits supplied by all alternative |
7 | | retail electric suppliers under this subparagraph (H) |
8 | | shall not exceed 9% of the Illinois target renewable |
9 | | energy credit quantity. The Illinois target renewable |
10 | | energy credit quantity for the delivery year beginning |
11 | | June 1, 2018 is 14.5% multiplied by the total amount of |
12 | | metered electricity (megawatt-hours) delivered in the |
13 | | delivery year immediately preceding that delivery |
14 | | year, provided that the 14.5% shall increase by 1.5% |
15 | | each delivery year thereafter to 25% by the delivery |
16 | | year beginning June 1, 2025, and thereafter the 25% |
17 | | value shall apply to each delivery year. |
18 | | If the requirements set forth in items (i) through |
19 | | (iii) of this subparagraph (H) are met, the charges |
20 | | that would otherwise be applicable to the retail |
21 | | customers of the alternative retail electric supplier |
22 | | under paragraph (6) of this subsection (c) for the |
23 | | applicable delivery year shall be reduced by the ratio |
24 | | of the quantity of renewable energy credits supplied by |
25 | | the alternative retail electric supplier compared to |
26 | | that supplier's target renewable energy credit |
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1 | | quantity. The supplier's target renewable energy |
2 | | credit quantity for the delivery year beginning June 1, |
3 | | 2018 is 14.5% multiplied by the total amount of metered |
4 | | electricity (megawatt-hours) delivered by the |
5 | | alternative retail supplier in that delivery year, |
6 | | provided that the 14.5% shall increase by 1.5% each |
7 | | delivery year thereafter to 25% by the delivery year |
8 | | beginning June 1, 2025, and thereafter the 25% value |
9 | | shall apply to each delivery year. |
10 | | On or before April 1 of each year, the Agency shall |
11 | | annually publish a report on its website that |
12 | | identifies the aggregate amount of renewable energy |
13 | | credits supplied by alternative retail electric |
14 | | suppliers under this subparagraph (H). |
15 | | (I) The Agency shall design its long-term renewable |
16 | | energy procurement plan to maximize the State's interest in |
17 | | the health, safety, and welfare of its residents, including |
18 | | but not limited to minimizing sulfur dioxide, nitrogen |
19 | | oxide, particulate matter and other pollution that |
20 | | adversely affects public health in this State, increasing |
21 | | fuel and resource diversity in this State, enhancing the |
22 | | reliability and resiliency of the electricity distribution |
23 | | system in this State, meeting goals to limit carbon dioxide |
24 | | emissions under federal or State law, and contributing to a |
25 | | cleaner and healthier environment for the citizens of this |
26 | | State. In order to further these legislative purposes, |
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1 | | renewable energy credits shall be eligible to be counted |
2 | | toward the renewable energy requirements of this |
3 | | subsection (c) if they are generated from facilities |
4 | | located in this State. The Agency may qualify renewable |
5 | | energy credits from facilities located in states adjacent |
6 | | to Illinois if the generator demonstrates and the Agency |
7 | | determines that the operation of such facility or |
8 | | facilities will help promote the State's interest in the |
9 | | health, safety, and welfare of its residents based on the |
10 | | public interest criteria described above. To ensure that |
11 | | the public interest criteria are applied to the procurement |
12 | | and given full effect, the Agency's long-term procurement |
13 | | plan shall describe in detail how each public interest |
14 | | factor shall be considered and weighted for facilities |
15 | | located in states adjacent to Illinois. |
16 | | (J) In order to promote the competitive development of |
17 | | renewable energy resources in furtherance of the State's |
18 | | interest in the health, safety, and welfare of its |
19 | | residents, renewable energy credits shall not be eligible |
20 | | to be counted toward the renewable energy requirements of |
21 | | this subsection (c) if they are sourced from a generating |
22 | | unit whose costs were being recovered through rates |
23 | | regulated by this State or any other state or states on or |
24 | | after January 1, 2017. Each contract executed to purchase |
25 | | renewable energy credits under this subsection (c) shall |
26 | | provide for the contract's termination if the costs of the |
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1 | | generating unit supplying the renewable energy credits |
2 | | subsequently begin to be recovered through rates regulated |
3 | | by this State or any other state or states; and each |
4 | | contract shall further provide that, in that event, the |
5 | | supplier of the credits must return 110% of all payments |
6 | | received under the contract. Amounts returned under the |
7 | | requirements of this subparagraph (J) shall be retained by |
8 | | the utility and all of these amounts shall be used for the |
9 | | procurement of additional renewable energy credits from |
10 | | new wind or new photovoltaic resources as defined in this |
11 | | subsection (c). The long-term plan shall provide that these |
12 | | renewable energy credits shall be procured in the next |
13 | | procurement event. |
14 | | Notwithstanding the limitations of this subparagraph |
15 | | (J), renewable energy credits sourced from generating |
16 | | units that are constructed, purchased, owned, or leased by |
17 | | an electric utility as part of an approved project, |
18 | | program, or pilot under Section 1-56 of this Act shall be |
19 | | eligible to be counted toward the renewable energy |
20 | | requirements of this subsection (c), regardless of how the |
21 | | costs of these units are recovered. |
22 | | (K) The long-term renewable resources procurement plan |
23 | | developed by the Agency in accordance with subparagraph (A) |
24 | | of this paragraph (1) shall include an Adjustable Block |
25 | | program for the procurement of renewable energy credits |
26 | | from new photovoltaic projects that are distributed |
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1 | | renewable energy generation devices or new photovoltaic |
2 | | community renewable generation projects. The Adjustable |
3 | | Block program shall be designed to provide a transparent |
4 | | schedule of prices and quantities to enable the |
5 | | photovoltaic market to scale up and for renewable energy |
6 | | credit prices to adjust at a predictable rate over time. |
7 | | The prices set by the Adjustable Block program can be |
8 | | reflected as a set value or as the product of a formula. |
9 | | The Adjustable Block program shall include for each |
10 | | category of eligible projects: a schedule of standard block |
11 | | purchase prices to be offered; a series of steps, with |
12 | | associated nameplate capacity and purchase prices that |
13 | | adjust from step to step; and automatic opening of the next |
14 | | step as soon as the nameplate capacity and available |
15 | | purchase prices for an open step are fully committed or |
16 | | reserved. Only projects energized on or after June 1, 2017 |
17 | | shall be eligible for the Adjustable Block program. For |
18 | | each block group the Agency shall determine the number of |
19 | | blocks, the amount of generation capacity in each block, |
20 | | and the purchase price for each block, provided that the |
21 | | purchase price provided and the total amount of generation |
22 | | in all blocks for all block groups shall be sufficient to |
23 | | meet the goals in this subsection (c). The Agency may |
24 | | periodically review its prior decisions establishing the |
25 | | number of blocks, the amount of generation capacity in each |
26 | | block, and the purchase price for each block, and may |
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1 | | propose, on an expedited basis, changes to these previously |
2 | | set values, including but not limited to redistributing |
3 | | these amounts and the available funds as necessary and |
4 | | appropriate, subject to Commission approval as part of the |
5 | | periodic plan revision process described in Section |
6 | | 16-111.5 of the Public Utilities Act. The Agency may define |
7 | | different block sizes, purchase prices, or other distinct |
8 | | terms and conditions for projects located in different |
9 | | utility service territories if the Agency deems it |
10 | | necessary to meet the goals in this subsection (c). |
11 | | The Adjustable Block program shall include at least the |
12 | | following block groups in at least the following amounts, |
13 | | which may be adjusted upon review by the Agency and |
14 | | approval by the Commission as described in this |
15 | | subparagraph (K): |
16 | | (i) At least 25% from distributed renewable energy |
17 | | generation devices with a nameplate capacity of no more |
18 | | than 10 kilowatts. |
19 | | (ii) At least 25% from distributed renewable |
20 | | energy generation devices with a nameplate capacity of |
21 | | more than 10 kilowatts and no more than 2,000 |
22 | | kilowatts. The Agency may create sub-categories within |
23 | | this category to account for the differences between |
24 | | projects for small commercial customers, large |
25 | | commercial customers, and public or non-profit |
26 | | customers. |
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1 | | (iii) At least 25% from photovoltaic community |
2 | | renewable generation projects. |
3 | | (iv) The remaining 25% shall be allocated as |
4 | | specified by the Agency in the long-term renewable |
5 | | resources procurement plan. |
6 | | The Adjustable Block program shall be designed to |
7 | | ensure that renewable energy credits are procured from |
8 | | photovoltaic distributed renewable energy generation |
9 | | devices and new photovoltaic community renewable energy |
10 | | generation projects in diverse locations , including urban |
11 | | and rural areas, and are not concentrated in a few |
12 | | geographic areas or excluding particular geographic areas . |
13 | | The Adjustable Block Program shall be designed to |
14 | | prioritize the procurement of renewable energy credits |
15 | | from new photovoltaic community renewable energy projects |
16 | | that are organized by local communities, sited in the |
17 | | communities they serve, or are also brownfield site |
18 | | photovoltaic projects, as defined in Section 1-10 of this |
19 | | Act, for a portion of the overall renewable energy credits |
20 | | to be procured from new photovoltaic community renewable |
21 | | energy projects. |
22 | | (L) The procurement of photovoltaic renewable energy |
23 | | credits under items (i) through (iv) of subparagraph (K) of |
24 | | this paragraph (1) shall be subject to the following |
25 | | contract and payment terms: |
26 | | (i) The Agency shall procure contracts of at least |
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1 | | 15 years in length. |
2 | | (ii) For those renewable energy credits that |
3 | | qualify and are procured under item (i) of subparagraph |
4 | | (K) of this paragraph (1), the renewable energy credit |
5 | | purchase price shall be paid in full by the contracting |
6 | | utilities at the time that the facility producing the |
7 | | renewable energy credits is interconnected at the |
8 | | distribution system level of the utility and |
9 | | energized. The electric utility shall receive and |
10 | | retire all renewable energy credits generated by the |
11 | | project for the first 15 years of operation. |
12 | | (iii) For those renewable energy credits that |
13 | | qualify and are procured under item (ii) and (iii) of |
14 | | subparagraph (K) of this paragraph (1) and any |
15 | | additional categories of distributed generation |
16 | | included in the long-term renewable resources |
17 | | procurement plan and approved by the Commission, 20 |
18 | | percent of the renewable energy credit purchase price |
19 | | shall be paid by the contracting utilities at the time |
20 | | that the facility producing the renewable energy |
21 | | credits is interconnected at the distribution system |
22 | | level of the utility and energized. The remaining |
23 | | portion shall be paid ratably over the subsequent |
24 | | 4-year period. The electric utility shall receive and |
25 | | retire all renewable energy credits generated by the |
26 | | project for the first 15 years of operation. |
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1 | | (iv) Each contract shall include provisions to |
2 | | ensure the delivery of the renewable energy credits for |
3 | | the full term of the contract. |
4 | | (v) The utility shall be the counterparty to the |
5 | | contracts executed under this subparagraph (L) that |
6 | | are approved by the Commission under the process |
7 | | described in Section 16-111.5 of the Public Utilities |
8 | | Act. No contract shall be executed for an amount that |
9 | | is less than one renewable energy credit per year. |
10 | | (vi) If, at any time, approved applications for the |
11 | | Adjustable Block program exceed funds collected by the |
12 | | electric utility or would cause the Agency to exceed |
13 | | the limitation described in subparagraph (E) of this |
14 | | paragraph (1) on the amount of renewable energy |
15 | | resources that may be procured, then the Agency shall |
16 | | consider future uncommitted funds to be reserved for |
17 | | these contracts on a first-come, first-served basis, |
18 | | with the delivery of renewable energy credits required |
19 | | beginning at the time that the reserved funds become |
20 | | available. |
21 | | (vii) Nothing in this Section shall require the |
22 | | utility to advance any payment or pay any amounts that |
23 | | exceed the actual amount of revenues collected by the |
24 | | utility under paragraph (6) of this subsection (c) and |
25 | | subsection (k) of Section 16-108 of the Public |
26 | | Utilities Act, and contracts executed under this |
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1 | | Section shall expressly incorporate this limitation. |
2 | | (M) The Agency shall be authorized to retain one or |
3 | | more experts or expert consulting firms to develop, |
4 | | administer, implement, operate, and evaluate the |
5 | | Adjustable Block program described in subparagraph (K) of |
6 | | this paragraph (1), and the Agency shall retain the |
7 | | consultant or consultants in the same manner, to the extent |
8 | | practicable, as the Agency retains others to administer |
9 | | provisions of this Act, including, but not limited to, the |
10 | | procurement administrator. The selection of experts and |
11 | | expert consulting firms and the procurement process |
12 | | described in this subparagraph (M) are exempt from the |
13 | | requirements of Section 20-10 of the Illinois Procurement |
14 | | Code, under Section 20-10 of that Code. The Agency shall |
15 | | strive to minimize administrative expenses in the |
16 | | implementation of the Adjustable Block program. |
17 | | The Agency and its consultant or consultants shall |
18 | | monitor block activity, share program activity with |
19 | | stakeholders and conduct regularly scheduled meetings to |
20 | | discuss program activity and market conditions. If |
21 | | necessary, the Agency may make prospective administrative |
22 | | adjustments to the Adjustable Block program design, such as |
23 | | redistributing available funds or making adjustments to |
24 | | purchase prices as necessary to achieve the goals of this |
25 | | subsection (c). Program modifications to any price, |
26 | | capacity block, or other program element that do not |
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1 | | deviate from the Commission's approved value by more than |
2 | | 25% shall take effect immediately and are not subject to |
3 | | Commission review and approval. Program modifications to |
4 | | any price, capacity block, or other program element that |
5 | | deviate more than 25% from the Commission's approved value |
6 | | must be approved by the Commission as a long-term plan |
7 | | amendment under Section 16-111.5 of the Public Utilities |
8 | | Act. The Agency shall consider stakeholder feedback when |
9 | | making adjustments to the Adjustable Block design and shall |
10 | | notify stakeholders in advance of any planned changes. |
11 | | (N) The long-term renewable resources procurement plan |
12 | | required by this subsection (c) shall include a community |
13 | | renewable generation program. The Agency shall establish |
14 | | the terms, conditions, and program requirements for |
15 | | community renewable generation projects with a goal to |
16 | | expand renewable energy generating facility access to a |
17 | | broader group of energy consumers, to ensure robust |
18 | | participation opportunities for residential and small |
19 | | commercial customers and those who cannot install |
20 | | renewable energy on their own properties. Any plan approved |
21 | | by the Commission shall allow subscriptions to community |
22 | | renewable generation projects to be portable and |
23 | | transferable. For purposes of this subparagraph (N), |
24 | | "portable" means that subscriptions may be retained by the |
25 | | subscriber even if the subscriber relocates or changes its |
26 | | address within the same utility service territory; and |
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1 | | "transferable" means that a subscriber may assign or sell |
2 | | subscriptions to another person within the same utility |
3 | | service territory. |
4 | | Electric utilities shall provide a monetary credit to a |
5 | | subscriber's subsequent bill for service for the |
6 | | proportional output of a community renewable generation |
7 | | project attributable to that subscriber as specified in |
8 | | Section 16-107.5 of the Public Utilities Act. |
9 | | The Agency shall purchase renewable energy credits |
10 | | from subscribed shares of photovoltaic community renewable |
11 | | generation projects through the Adjustable Block program |
12 | | described in subparagraph (K) of this paragraph (1) or |
13 | | through the Illinois Solar for All Program described in |
14 | | Section 1-56 of this Act. The electric utility shall |
15 | | purchase any unsubscribed energy from community renewable |
16 | | generation projects that are Qualifying Facilities ("QF") |
17 | | under the electric utility's tariff for purchasing the |
18 | | output from QFs under Public Utilities Regulatory Policies |
19 | | Act of 1978. |
20 | | The owners of and any subscribers to a community |
21 | | renewable generation project shall not be considered |
22 | | public utilities or alternative retail electricity |
23 | | suppliers under the Public Utilities Act solely as a result |
24 | | of their interest in or subscription to a community |
25 | | renewable generation project and shall not be required to |
26 | | become an alternative retail electric supplier by |
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1 | | participating in a community renewable generation project |
2 | | with a public utility. |
3 | | (O) For the delivery year beginning June 1, 2018, the |
4 | | long-term renewable resources procurement plan required by |
5 | | this subsection (c) shall provide for the Agency to procure |
6 | | contracts to continue offering the Illinois Solar for All |
7 | | Program described in subsection (b) of Section 1-56 of this |
8 | | Act, and the contracts approved by the Commission shall be |
9 | | executed by the utilities that are subject to this |
10 | | subsection (c). The long-term renewable resources |
11 | | procurement plan shall allocate 5% of the funds available |
12 | | under the plan for the applicable delivery year, or |
13 | | $10,000,000 per delivery year, whichever is greater, to |
14 | | fund the programs, and the plan shall determine the amount |
15 | | of funding to be apportioned to the programs identified in |
16 | | subsection (b) of Section 1-56 of this Act; provided that |
17 | | for the delivery years beginning June 1, 2017, June 1, |
18 | | 2021, and June 1, 2025, the long-term renewable resources |
19 | | procurement plan shall allocate 10% of the funds available |
20 | | under the plan for the applicable delivery year, or |
21 | | $20,000,000 per delivery year, whichever is greater, and |
22 | | $10,000,000 of such funds in such year shall be used by an |
23 | | electric utility that serves more than 3,000,000 retail |
24 | | customers in the State to implement a Commission-approved |
25 | | plan under Section 16-108.12 of the Public Utilities Act. |
26 | | In making the determinations required under this |
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1 | | subparagraph (O), the Commission shall consider the |
2 | | experience and performance under the programs and any |
3 | | evaluation reports. The Commission shall also provide for |
4 | | an independent evaluation of those programs on a periodic |
5 | | basis that are funded under this subparagraph (O). |
6 | | (P) For the delivery year beginning June 1, 2021, the |
7 | | long-term renewable resources procurement plan required by |
8 | | this subsection (c) shall also include and account for the |
9 | | annual procurement of new long-term contracts, including |
10 | | bundled contracts, as described in subsection (j) of this |
11 | | Section, from new wind projects and new photovoltaic |
12 | | projects such that, by the end of the 2030 delivery year: |
13 | | (i) at least 25,000,000 renewable energy credits |
14 | | for each delivery year shall come from new wind |
15 | | projects; and |
16 | | (ii) at least 25,000,000 renewable energy credits |
17 | | for each delivery year shall come from new photovoltaic |
18 | | projects. |
19 | | The gradual increase in renewable resource procurement |
20 | | discussed in this subparagraph (P) shall involve annual |
21 | | procurements of new wind and new photovoltaic projects and, |
22 | | in the case of the Adjustable Block Program created by |
23 | | subparagraph (K) of this subsection (c), the annual release |
24 | | of new blocks of capacity each year with the goal of |
25 | | encouraging stability and steady growth in the solar market |
26 | | and avoiding boom-bust cycles. |
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1 | | In developing the long-term renewable resources |
2 | | procurement plan, the Agency shall develop bidding |
3 | | criteria to account for the ability of new photovoltaic and |
4 | | wind projects to deliver additional benefits for Illinois |
5 | | such as agriculture and pollinator-friendly projects, |
6 | | brownfield redevelopment, water-pollution buffers, and |
7 | | other land-use or environmental benefits. |
8 | | In this Section: |
9 | | "New wind projects" means wind renewable energy |
10 | | facilities that are energized after June 1, 2017 for the |
11 | | delivery year commencing June 1, 2017 or within 3 years |
12 | | after the date the Commission approves contracts for |
13 | | subsequent delivery years. |
14 | | "New photovoltaic projects" means photovoltaic |
15 | | renewable energy facilities that are energized after June |
16 | | 1, 2017. |
17 | | (Q) Beginning with the 2019 update to the long-term |
18 | | renewable resources procurement plan required by this |
19 | | subsection (c), the Agency shall evaluate the budget |
20 | | necessary to fund: |
21 | | (i) purchases of renewable energy credits under |
22 | | existing contractual obligations; |
23 | | (ii) the Illinois Solar for All Program, related |
24 | | grassroots education and expansion goals under Section |
25 | | 1-56(b)(2-8) of the Illinois Power Agency Act; |
26 | | (iii) purchases of renewable energy credits |
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1 | | necessary to comply with the new wind and new |
2 | | photovoltaic project requirements described in items |
3 | | (i) through (iii) of subparagraph (C) of this paragraph |
4 | | (1); and |
5 | | (iv) purchases of renewable energy credits |
6 | | necessary to comply with the new wind project and new |
7 | | photovoltaic project procurement requirements |
8 | | described in subparagraph (P) of this paragraph (1). |
9 | | Following the delivery year 2021, the Agency shall |
10 | | review the budget necessary to fund items (i) through (iv) |
11 | | of this subparagraph (Q) to determine if that budget |
12 | | exceeds the limitation on the amount of renewable energy |
13 | | resources procured in subparagraph (E) of this paragraph |
14 | | (1) when combined with savings achieved by the carbon-free |
15 | | resources procured in subsection (k) of this Section. If |
16 | | so, the Agency shall propose an alternative limitation |
17 | | which the Commission shall review and approve if the |
18 | | Commission finds an alternative limitation is necessary to |
19 | | achieve the requirements of items (i) through (iv) of this |
20 | | subparagraph (Q). The Commission shall find an alternative |
21 | | limitation necessary only if it determines it is a |
22 | | cost-effective way to achieve the goals of subsection (c) |
23 | | and paragraphs (2) through (8) of subsection (b) and as |
24 | | part of the review of the Agency's procurement plan for the |
25 | | delivery year following the year in which the Agency |
26 | | concludes an alternative limitation is necessary as |
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1 | | described by the procurement process contained in Section |
2 | | 16-111.5 of the Public Utilities Act. |
3 | | (1.5) No later than May 31, 2021, all Illinois electric |
4 | | cooperatives and municipal utilities shall develop a plan |
5 | | to ensure that their members and customers have access to |
6 | | renewable energy on a reasonably equivalent basis to all |
7 | | other residents in the State, including the overall |
8 | | percentage goals listed in subparagraph (A) of paragraph |
9 | | (1) of this Section and the carbon-free resources goals of |
10 | | subsection (k) of this Section 1-75. These plans shall be |
11 | | developed through a public process involving municipal |
12 | | utility and cooperative members, customers, and other |
13 | | members of the public, and shall be filed with the Illinois |
14 | | Commerce Commission at least every 2 years. |
15 | | (2) (Blank). |
16 | | (3) (Blank). |
17 | | (4) The electric utility shall retire all renewable |
18 | | energy credits used to comply with the standard. |
19 | | (5) Beginning with the 2010 delivery year and ending |
20 | | June 1, 2017, an electric utility subject to this |
21 | | subsection (c) shall apply the lesser of the maximum |
22 | | alternative compliance payment rate or the most recent |
23 | | estimated alternative compliance payment rate for its |
24 | | service territory for the corresponding compliance period, |
25 | | established pursuant to subsection (d) of Section 16-115D |
26 | | of the Public Utilities Act to its retail customers that |
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1 | | take service pursuant to the electric utility's hourly |
2 | | pricing tariff or tariffs. The electric utility shall |
3 | | retain all amounts collected as a result of the application |
4 | | of the alternative compliance payment rate or rates to such |
5 | | customers, and, beginning in 2011, the utility shall |
6 | | include in the information provided under item (1) of |
7 | | subsection (d) of Section 16-111.5 of the Public Utilities |
8 | | Act the amounts collected under the alternative compliance |
9 | | payment rate or rates for the prior year ending May 31. |
10 | | Notwithstanding any limitation on the procurement of |
11 | | renewable energy resources imposed by item (2) of this |
12 | | subsection (c), the Agency shall increase its spending on |
13 | | the purchase of renewable energy resources to be procured |
14 | | by the electric utility for the next plan year by an amount |
15 | | equal to the amounts collected by the utility under the |
16 | | alternative compliance payment rate or rates in the prior |
17 | | year ending May 31. |
18 | | (6) The electric utility shall be entitled to recover |
19 | | all of its costs associated with the procurement of |
20 | | renewable energy credits under plans approved under this |
21 | | Section and Section 16-111.5 of the Public Utilities Act. |
22 | | These costs shall include associated reasonable expenses |
23 | | for implementing the procurement programs, including, but |
24 | | not limited to, the costs of administering and evaluating |
25 | | the Adjustable Block program, through an automatic |
26 | | adjustment clause tariff in accordance with subsection (k) |
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1 | | of Section 16-108 of the Public Utilities Act. |
2 | | (7) Renewable energy credits procured from new |
3 | | photovoltaic projects or new distributed renewable energy |
4 | | generation devices under this Section after June 1, 2017 |
5 | | (the effective date of Public Act 99-906) must be procured |
6 | | from devices installed by a qualified person in compliance |
7 | | with the requirements of Section 16-128A of the Public |
8 | | Utilities Act and any rules or regulations adopted |
9 | | thereunder. |
10 | | In meeting the renewable energy requirements of this |
11 | | subsection (c), to the extent feasible and consistent with |
12 | | State and federal law, the renewable energy credit |
13 | | procurements, Adjustable Block solar program, and |
14 | | community renewable generation program shall provide |
15 | | employment opportunities for all segments of the |
16 | | population and workforce, including minority-owned and |
17 | | female-owned business enterprises, and shall not, |
18 | | consistent with State and federal law, discriminate based |
19 | | on race or socioeconomic status. Specifically, as the |
20 | | Agency conducts competitive procurement processes and |
21 | | implements programs to procure renewable energy credits |
22 | | identified in the long-term renewable resources |
23 | | procurement plan, the Agency must preference the |
24 | | procurement of renewable energy credits from those |
25 | | Approved Vendors and companies that meet multiple Equity |
26 | | Actions, including, but not limited to, the following: |
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1 | | (A) Hiring Equity Action: 30% of the company's |
2 | | workforce (measured by FTEs) are people of color |
3 | | (members of a racial or ethnic minority group) and |
4 | | receive at or above the prevailing wage. |
5 | | (B) Clean Jobs Workforce Hubs Action: 30% of the |
6 | | workers associated with the project are graduates or |
7 | | trainees from the Clean Jobs Workforce Hubs programs, |
8 | | or equivalent certification, and paid at or above the |
9 | | prevailing wage. |
10 | | (C) Disadvantaged Business Enterprise Action: |
11 | | being an entity defined under Section 2 of the Business |
12 | | Enterprise for Minorities, Women, and Persons with |
13 | | Disabilities Act. |
14 | | (D) Contracting Equity Action: 51% of the |
15 | | company's subcontractors or vendors are entities |
16 | | defined under Section 2 of the Business Enterprise for |
17 | | Minorities, Women, and Persons with Disabilities Act |
18 | | or 30% of the workers associated with the project, |
19 | | including from all subcontractors and vendors, are |
20 | | people of color (members of a racial or ethnic minority |
21 | | group). |
22 | | (E) Community Benefits Action: (i) for projects |
23 | | 100kW in size or larger, project has an executed |
24 | | Community Benefits Agreement that could include, but |
25 | | is not limited to, a commitment to hire local workers, |
26 | | union workers, displaced fossil fuel workers |
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1 | | transitioning to clean energy work, or Clean Jobs |
2 | | Workforce Hubs graduates, a commitment to pay workers |
3 | | at or above the prevailing wage, and a commitment to |
4 | | give communities ownership opportunities in clean |
5 | | energy projects; and (ii) for projects under 100kW in |
6 | | size, companies pay their workforce at or above the |
7 | | prevailing wage. |
8 | | (F) Small Business Action: company's workforce is |
9 | | comprised of 3 or fewer full-time employees. |
10 | | (d) Clean coal portfolio standard. |
11 | | (1) The procurement plans shall include electricity |
12 | | generated using clean coal. Each utility shall enter into |
13 | | one or more sourcing agreements with the initial clean coal |
14 | | facility, as provided in paragraph (3) of this subsection |
15 | | (d), covering electricity generated by the initial clean |
16 | | coal facility representing at least 5% of each utility's |
17 | | total supply to serve the load of eligible retail customers |
18 | | in 2015 and each year thereafter, as described in paragraph |
19 | | (3) of this subsection (d), subject to the limits specified |
20 | | in paragraph (2) of this subsection (d). It is the goal of |
21 | | the State that by January 1, 2025, 25% of the electricity |
22 | | used in the State shall be generated by cost-effective |
23 | | clean coal facilities. For purposes of this subsection (d), |
24 | | "cost-effective" means that the expenditures pursuant to |
25 | | such sourcing agreements do not cause the limit stated in |
26 | | paragraph (2) of this subsection (d) to be exceeded and do |
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1 | | not exceed cost-based benchmarks, which shall be developed |
2 | | to assess all expenditures pursuant to such sourcing |
3 | | agreements covering electricity generated by clean coal |
4 | | facilities, other than the initial clean coal facility, by |
5 | | the procurement administrator, in consultation with the |
6 | | Commission staff, Agency staff, and the procurement |
7 | | monitor and shall be subject to Commission review and |
8 | | approval. |
9 | | A utility party to a sourcing agreement shall |
10 | | immediately retire any emission credits that it receives in |
11 | | connection with the electricity covered by such agreement. |
12 | | Utilities shall maintain adequate records documenting |
13 | | the purchases under the sourcing agreement to comply with |
14 | | this subsection (d) and shall file an accounting with the |
15 | | load forecast that must be filed with the Agency by July 15 |
16 | | of each year, in accordance with subsection (d) of Section |
17 | | 16-111.5 of the Public Utilities Act. |
18 | | A utility shall be deemed to have complied with the |
19 | | clean coal portfolio standard specified in this subsection |
20 | | (d) if the utility enters into a sourcing agreement as |
21 | | required by this subsection (d). |
22 | | (2) For purposes of this subsection (d), the required |
23 | | execution of sourcing agreements with the initial clean |
24 | | coal facility for a particular year shall be measured as a |
25 | | percentage of the actual amount of electricity |
26 | | (megawatt-hours) supplied by the electric utility to |
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1 | | eligible retail customers in the planning year ending |
2 | | immediately prior to the agreement's execution. For |
3 | | purposes of this subsection (d), the amount paid per |
4 | | kilowatthour means the total amount paid for electric |
5 | | service expressed on a per kilowatthour basis. For purposes |
6 | | of this subsection (d), the total amount paid for electric |
7 | | service includes without limitation amounts paid for |
8 | | supply, transmission, distribution, surcharges and add-on |
9 | | taxes. |
10 | | Notwithstanding the requirements of this subsection |
11 | | (d), the total amount paid under sourcing agreements with |
12 | | clean coal facilities pursuant to the procurement plan for |
13 | | any given year shall be reduced by an amount necessary to |
14 | | limit the annual estimated average net increase due to the |
15 | | costs of these resources included in the amounts paid by |
16 | | eligible retail customers in connection with electric |
17 | | service to: |
18 | | (A) in 2010, no more than 0.5% of the amount paid |
19 | | per kilowatthour by those customers during the year |
20 | | ending May 31, 2009; |
21 | | (B) in 2011, the greater of an additional 0.5% of |
22 | | the amount paid per kilowatthour by those customers |
23 | | during the year ending May 31, 2010 or 1% of the amount |
24 | | paid per kilowatthour by those customers during the |
25 | | year ending May 31, 2009; |
26 | | (C) in 2012, the greater of an additional 0.5% of |
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1 | | the amount paid per kilowatthour by those customers |
2 | | during the year ending May 31, 2011 or 1.5% of the |
3 | | amount paid per kilowatthour by those customers during |
4 | | the year ending May 31, 2009; |
5 | | (D) in 2013, the greater of an additional 0.5% of |
6 | | the amount paid per kilowatthour by those customers |
7 | | during the year ending May 31, 2012 or 2% of the amount |
8 | | paid per kilowatthour by those customers during the |
9 | | year ending May 31, 2009; and |
10 | | (E) thereafter, the total amount paid under |
11 | | sourcing agreements with clean coal facilities |
12 | | pursuant to the procurement plan for any single year |
13 | | shall be reduced by an amount necessary to limit the |
14 | | estimated average net increase due to the cost of these |
15 | | resources included in the amounts paid by eligible |
16 | | retail customers in connection with electric service |
17 | | to no more than the greater of (i) 2.015% of the amount |
18 | | paid per kilowatthour by those customers during the |
19 | | year ending May 31, 2009 or (ii) the incremental amount |
20 | | per kilowatthour paid for these resources in 2013. |
21 | | These requirements may be altered only as provided by |
22 | | statute. |
23 | | No later than June 30, 2015, the Commission shall |
24 | | review the limitation on the total amount paid under |
25 | | sourcing agreements, if any, with clean coal facilities |
26 | | pursuant to this subsection (d) and report to the General |
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1 | | Assembly its findings as to whether that limitation unduly |
2 | | constrains the amount of electricity generated by |
3 | | cost-effective clean coal facilities that is covered by |
4 | | sourcing agreements. |
5 | | (3) Initial clean coal facility. In order to promote |
6 | | development of clean coal facilities in Illinois, each |
7 | | electric utility subject to this Section shall execute a |
8 | | sourcing agreement to source electricity from a proposed |
9 | | clean coal facility in Illinois (the "initial clean coal |
10 | | facility") that will have a nameplate capacity of at least |
11 | | 500 MW when commercial operation commences, that has a |
12 | | final Clean Air Act permit on June 1, 2009 (the effective |
13 | | date of Public Act 95-1027), and that will meet the |
14 | | definition of clean coal facility in Section 1-10 of this |
15 | | Act when commercial operation commences. The sourcing |
16 | | agreements with this initial clean coal facility shall be |
17 | | subject to both approval of the initial clean coal facility |
18 | | by the General Assembly and satisfaction of the |
19 | | requirements of paragraph (4) of this subsection (d) and |
20 | | shall be executed within 90 days after any such approval by |
21 | | the General Assembly. The Agency and the Commission shall |
22 | | have authority to inspect all books and records associated |
23 | | with the initial clean coal facility during the term of |
24 | | such a sourcing agreement. A utility's sourcing agreement |
25 | | for electricity produced by the initial clean coal facility |
26 | | shall include: |
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1 | | (A) a formula contractual price (the "contract |
2 | | price") approved pursuant to paragraph (4) of this |
3 | | subsection (d), which shall: |
4 | | (i) be determined using a cost of service |
5 | | methodology employing either a level or deferred |
6 | | capital recovery component, based on a capital |
7 | | structure consisting of 45% equity and 55% debt, |
8 | | and a return on equity as may be approved by the |
9 | | Federal Energy Regulatory Commission, which in any |
10 | | case may not exceed the lower of 11.5% or the rate |
11 | | of return approved by the General Assembly |
12 | | pursuant to paragraph (4) of this subsection (d); |
13 | | and |
14 | | (ii) provide that all miscellaneous net |
15 | | revenue, including but not limited to net revenue |
16 | | from the sale of emission allowances, if any, |
17 | | substitute natural gas, if any, grants or other |
18 | | support provided by the State of Illinois or the |
19 | | United States Government, firm transmission |
20 | | rights, if any, by-products produced by the |
21 | | facility, energy or capacity derived from the |
22 | | facility and not covered by a sourcing agreement |
23 | | pursuant to paragraph (3) of this subsection (d) or |
24 | | item (5) of subsection (d) of Section 16-115 of the |
25 | | Public Utilities Act, whether generated from the |
26 | | synthesis gas derived from coal, from SNG, or from |
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1 | | natural gas, shall be credited against the revenue |
2 | | requirement for this initial clean coal facility; |
3 | | (B) power purchase provisions, which shall: |
4 | | (i) provide that the utility party to such |
5 | | sourcing agreement shall pay the contract price |
6 | | for electricity delivered under such sourcing |
7 | | agreement; |
8 | | (ii) require delivery of electricity to the |
9 | | regional transmission organization market of the |
10 | | utility that is party to such sourcing agreement; |
11 | | (iii) require the utility party to such |
12 | | sourcing agreement to buy from the initial clean |
13 | | coal facility in each hour an amount of energy |
14 | | equal to all clean coal energy made available from |
15 | | the initial clean coal facility during such hour |
16 | | times a fraction, the numerator of which is such |
17 | | utility's retail market sales of electricity |
18 | | (expressed in kilowatthours sold) in the State |
19 | | during the prior calendar month and the |
20 | | denominator of which is the total retail market |
21 | | sales of electricity (expressed in kilowatthours |
22 | | sold) in the State by utilities during such prior |
23 | | month and the sales of electricity (expressed in |
24 | | kilowatthours sold) in the State by alternative |
25 | | retail electric suppliers during such prior month |
26 | | that are subject to the requirements of this |
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1 | | subsection (d) and paragraph (5) of subsection (d) |
2 | | of Section 16-115 of the Public Utilities Act, |
3 | | provided that the amount purchased by the utility |
4 | | in any year will be limited by paragraph (2) of |
5 | | this subsection (d); and |
6 | | (iv) be considered pre-existing contracts in |
7 | | such utility's procurement plans for eligible |
8 | | retail customers; |
9 | | (C) contract for differences provisions, which |
10 | | shall: |
11 | | (i) require the utility party to such sourcing |
12 | | agreement to contract with the initial clean coal |
13 | | facility in each hour with respect to an amount of |
14 | | energy equal to all clean coal energy made |
15 | | available from the initial clean coal facility |
16 | | during such hour times a fraction, the numerator of |
17 | | which is such utility's retail market sales of |
18 | | electricity (expressed in kilowatthours sold) in |
19 | | the utility's service territory in the State |
20 | | during the prior calendar month and the |
21 | | denominator of which is the total retail market |
22 | | sales of electricity (expressed in kilowatthours |
23 | | sold) in the State by utilities during such prior |
24 | | month and the sales of electricity (expressed in |
25 | | kilowatthours sold) in the State by alternative |
26 | | retail electric suppliers during such prior month |
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1 | | that are subject to the requirements of this |
2 | | subsection (d) and paragraph (5) of subsection (d) |
3 | | of Section 16-115 of the Public Utilities Act, |
4 | | provided that the amount paid by the utility in any |
5 | | year will be limited by paragraph (2) of this |
6 | | subsection (d); |
7 | | (ii) provide that the utility's payment |
8 | | obligation in respect of the quantity of |
9 | | electricity determined pursuant to the preceding |
10 | | clause (i) shall be limited to an amount equal to |
11 | | (1) the difference between the contract price |
12 | | determined pursuant to subparagraph (A) of |
13 | | paragraph (3) of this subsection (d) and the |
14 | | day-ahead price for electricity delivered to the |
15 | | regional transmission organization market of the |
16 | | utility that is party to such sourcing agreement |
17 | | (or any successor delivery point at which such |
18 | | utility's supply obligations are financially |
19 | | settled on an hourly basis) (the "reference |
20 | | price") on the day preceding the day on which the |
21 | | electricity is delivered to the initial clean coal |
22 | | facility busbar, multiplied by (2) the quantity of |
23 | | electricity determined pursuant to the preceding |
24 | | clause (i); and |
25 | | (iii) not require the utility to take physical |
26 | | delivery of the electricity produced by the |
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1 | | facility; |
2 | | (D) general provisions, which shall: |
3 | | (i) specify a term of no more than 30 years, |
4 | | commencing on the commercial operation date of the |
5 | | facility; |
6 | | (ii) provide that utilities shall maintain |
7 | | adequate records documenting purchases under the |
8 | | sourcing agreements entered into to comply with |
9 | | this subsection (d) and shall file an accounting |
10 | | with the load forecast that must be filed with the |
11 | | Agency by July 15 of each year, in accordance with |
12 | | subsection (d) of Section 16-111.5 of the Public |
13 | | Utilities Act; |
14 | | (iii) provide that all costs associated with |
15 | | the initial clean coal facility will be |
16 | | periodically reported to the Federal Energy |
17 | | Regulatory Commission and to purchasers in |
18 | | accordance with applicable laws governing |
19 | | cost-based wholesale power contracts; |
20 | | (iv) permit the Illinois Power Agency to |
21 | | assume ownership of the initial clean coal |
22 | | facility, without monetary consideration and |
23 | | otherwise on reasonable terms acceptable to the |
24 | | Agency, if the Agency so requests no less than 3 |
25 | | years prior to the end of the stated contract term; |
26 | | (v) require the owner of the initial clean coal |
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1 | | facility to provide documentation to the |
2 | | Commission each year, starting in the facility's |
3 | | first year of commercial operation, accurately |
4 | | reporting the quantity of carbon emissions from |
5 | | the facility that have been captured and |
6 | | sequestered and report any quantities of carbon |
7 | | released from the site or sites at which carbon |
8 | | emissions were sequestered in prior years, based |
9 | | on continuous monitoring of such sites. If, in any |
10 | | year after the first year of commercial operation, |
11 | | the owner of the facility fails to demonstrate that |
12 | | the initial clean coal facility captured and |
13 | | sequestered at least 50% of the total carbon |
14 | | emissions that the facility would otherwise emit |
15 | | or that sequestration of emissions from prior |
16 | | years has failed, resulting in the release of |
17 | | carbon dioxide into the atmosphere, the owner of |
18 | | the facility must offset excess emissions. Any |
19 | | such carbon offsets must be permanent, additional, |
20 | | verifiable, real, located within the State of |
21 | | Illinois, and legally and practicably enforceable. |
22 | | The cost of such offsets for the facility that are |
23 | | not recoverable shall not exceed $15 million in any |
24 | | given year. No costs of any such purchases of |
25 | | carbon offsets may be recovered from a utility or |
26 | | its customers. All carbon offsets purchased for |
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1 | | this purpose and any carbon emission credits |
2 | | associated with sequestration of carbon from the |
3 | | facility must be permanently retired. The initial |
4 | | clean coal facility shall not forfeit its |
5 | | designation as a clean coal facility if the |
6 | | facility fails to fully comply with the applicable |
7 | | carbon sequestration requirements in any given |
8 | | year, provided the requisite offsets are |
9 | | purchased. However, the Attorney General, on |
10 | | behalf of the People of the State of Illinois, may |
11 | | specifically enforce the facility's sequestration |
12 | | requirement and the other terms of this contract |
13 | | provision. Compliance with the sequestration |
14 | | requirements and offset purchase requirements |
15 | | specified in paragraph (3) of this subsection (d) |
16 | | shall be reviewed annually by an independent |
17 | | expert retained by the owner of the initial clean |
18 | | coal facility, with the advance written approval |
19 | | of the Attorney General. The Commission may, in the |
20 | | course of the review specified in item (vii), |
21 | | reduce the allowable return on equity for the |
22 | | facility if the facility willfully fails to comply |
23 | | with the carbon capture and sequestration |
24 | | requirements set forth in this item (v); |
25 | | (vi) include limits on, and accordingly |
26 | | provide for modification of, the amount the |
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1 | | utility is required to source under the sourcing |
2 | | agreement consistent with paragraph (2) of this |
3 | | subsection (d); |
4 | | (vii) require Commission review: (1) to |
5 | | determine the justness, reasonableness, and |
6 | | prudence of the inputs to the formula referenced in |
7 | | subparagraphs (A)(i) through (A)(iii) of paragraph |
8 | | (3) of this subsection (d), prior to an adjustment |
9 | | in those inputs including, without limitation, the |
10 | | capital structure and return on equity, fuel |
11 | | costs, and other operations and maintenance costs |
12 | | and (2) to approve the costs to be passed through |
13 | | to customers under the sourcing agreement by which |
14 | | the utility satisfies its statutory obligations. |
15 | | Commission review shall occur no less than every 3 |
16 | | years, regardless of whether any adjustments have |
17 | | been proposed, and shall be completed within 9 |
18 | | months; |
19 | | (viii) limit the utility's obligation to such |
20 | | amount as the utility is allowed to recover through |
21 | | tariffs filed with the Commission, provided that |
22 | | neither the clean coal facility nor the utility |
23 | | waives any right to assert federal pre-emption or |
24 | | any other argument in response to a purported |
25 | | disallowance of recovery costs; |
26 | | (ix) limit the utility's or alternative retail |
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1 | | electric supplier's obligation to incur any |
2 | | liability until such time as the facility is in |
3 | | commercial operation and generating power and |
4 | | energy and such power and energy is being delivered |
5 | | to the facility busbar; |
6 | | (x) provide that the owner or owners of the |
7 | | initial clean coal facility, which is the |
8 | | counterparty to such sourcing agreement, shall |
9 | | have the right from time to time to elect whether |
10 | | the obligations of the utility party thereto shall |
11 | | be governed by the power purchase provisions or the |
12 | | contract for differences provisions; |
13 | | (xi) append documentation showing that the |
14 | | formula rate and contract, insofar as they relate |
15 | | to the power purchase provisions, have been |
16 | | approved by the Federal Energy Regulatory |
17 | | Commission pursuant to Section 205 of the Federal |
18 | | Power Act; |
19 | | (xii) provide that any changes to the terms of |
20 | | the contract, insofar as such changes relate to the |
21 | | power purchase provisions, are subject to review |
22 | | under the public interest standard applied by the |
23 | | Federal Energy Regulatory Commission pursuant to |
24 | | Sections 205 and 206 of the Federal Power Act; and |
25 | | (xiii) conform with customary lender |
26 | | requirements in power purchase agreements used as |
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1 | | the basis for financing non-utility generators. |
2 | | (4) Effective date of sourcing agreements with the |
3 | | initial clean coal facility. Any proposed sourcing |
4 | | agreement with the initial clean coal facility shall not |
5 | | become effective unless the following reports are prepared |
6 | | and submitted and authorizations and approvals obtained: |
7 | | (i) Facility cost report. The owner of the initial |
8 | | clean coal facility shall submit to the Commission, the |
9 | | Agency, and the General Assembly a front-end |
10 | | engineering and design study, a facility cost report, |
11 | | method of financing (including but not limited to |
12 | | structure and associated costs), and an operating and |
13 | | maintenance cost quote for the facility (collectively |
14 | | "facility cost report"), which shall be prepared in |
15 | | accordance with the requirements of this paragraph (4) |
16 | | of subsection (d) of this Section, and shall provide |
17 | | the Commission and the Agency access to the work |
18 | | papers, relied upon documents, and any other backup |
19 | | documentation related to the facility cost report. |
20 | | (ii) Commission report. Within 6 months following |
21 | | receipt of the facility cost report, the Commission, in |
22 | | consultation with the Agency, shall submit a report to |
23 | | the General Assembly setting forth its analysis of the |
24 | | facility cost report. Such report shall include, but |
25 | | not be limited to, a comparison of the costs associated |
26 | | with electricity generated by the initial clean coal |
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1 | | facility to the costs associated with electricity |
2 | | generated by other types of generation facilities, an |
3 | | analysis of the rate impacts on residential and small |
4 | | business customers over the life of the sourcing |
5 | | agreements, and an analysis of the likelihood that the |
6 | | initial clean coal facility will commence commercial |
7 | | operation by and be delivering power to the facility's |
8 | | busbar by 2016. To assist in the preparation of its |
9 | | report, the Commission, in consultation with the |
10 | | Agency, may hire one or more experts or consultants, |
11 | | the costs of which shall be paid for by the owner of |
12 | | the initial clean coal facility. The Commission and |
13 | | Agency may begin the process of selecting such experts |
14 | | or consultants prior to receipt of the facility cost |
15 | | report. |
16 | | (iii) General Assembly approval. The proposed |
17 | | sourcing agreements shall not take effect unless, |
18 | | based on the facility cost report and the Commission's |
19 | | report, the General Assembly enacts authorizing |
20 | | legislation approving (A) the projected price, stated |
21 | | in cents per kilowatthour, to be charged for |
22 | | electricity generated by the initial clean coal |
23 | | facility, (B) the projected impact on residential and |
24 | | small business customers' bills over the life of the |
25 | | sourcing agreements, and (C) the maximum allowable |
26 | | return on equity for the project; and |
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1 | | (iv) Commission review. If the General Assembly |
2 | | enacts authorizing legislation pursuant to |
3 | | subparagraph (iii) approving a sourcing agreement, the |
4 | | Commission shall, within 90 days of such enactment, |
5 | | complete a review of such sourcing agreement. During |
6 | | such time period, the Commission shall implement any |
7 | | directive of the General Assembly, resolve any |
8 | | disputes between the parties to the sourcing agreement |
9 | | concerning the terms of such agreement, approve the |
10 | | form of such agreement, and issue an order finding that |
11 | | the sourcing agreement is prudent and reasonable. |
12 | | The facility cost report shall be prepared as follows: |
13 | | (A) The facility cost report shall be prepared by |
14 | | duly licensed engineering and construction firms |
15 | | detailing the estimated capital costs payable to one or |
16 | | more contractors or suppliers for the engineering, |
17 | | procurement and construction of the components |
18 | | comprising the initial clean coal facility and the |
19 | | estimated costs of operation and maintenance of the |
20 | | facility. The facility cost report shall include: |
21 | | (i) an estimate of the capital cost of the core |
22 | | plant based on one or more front end engineering |
23 | | and design studies for the gasification island and |
24 | | related facilities. The core plant shall include |
25 | | all civil, structural, mechanical, electrical, |
26 | | control, and safety systems. |
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1 | | (ii) an estimate of the capital cost of the |
2 | | balance of the plant, including any capital costs |
3 | | associated with sequestration of carbon dioxide |
4 | | emissions and all interconnects and interfaces |
5 | | required to operate the facility, such as |
6 | | transmission of electricity, construction or |
7 | | backfeed power supply, pipelines to transport |
8 | | substitute natural gas or carbon dioxide, potable |
9 | | water supply, natural gas supply, water supply, |
10 | | water discharge, landfill, access roads, and coal |
11 | | delivery. |
12 | | The quoted construction costs shall be expressed |
13 | | in nominal dollars as of the date that the quote is |
14 | | prepared and shall include capitalized financing costs |
15 | | during construction,
taxes, insurance, and other |
16 | | owner's costs, and an assumed escalation in materials |
17 | | and labor beyond the date as of which the construction |
18 | | cost quote is expressed. |
19 | | (B) The front end engineering and design study for |
20 | | the gasification island and the cost study for the |
21 | | balance of plant shall include sufficient design work |
22 | | to permit quantification of major categories of |
23 | | materials, commodities and labor hours, and receipt of |
24 | | quotes from vendors of major equipment required to |
25 | | construct and operate the clean coal facility. |
26 | | (C) The facility cost report shall also include an |
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1 | | operating and maintenance cost quote that will provide |
2 | | the estimated cost of delivered fuel, personnel, |
3 | | maintenance contracts, chemicals, catalysts, |
4 | | consumables, spares, and other fixed and variable |
5 | | operations and maintenance costs. The delivered fuel |
6 | | cost estimate will be provided by a recognized third |
7 | | party expert or experts in the fuel and transportation |
8 | | industries. The balance of the operating and |
9 | | maintenance cost quote, excluding delivered fuel |
10 | | costs, will be developed based on the inputs provided |
11 | | by duly licensed engineering and construction firms |
12 | | performing the construction cost quote, potential |
13 | | vendors under long-term service agreements and plant |
14 | | operating agreements, or recognized third party plant |
15 | | operator or operators. |
16 | | The operating and maintenance cost quote |
17 | | (including the cost of the front end engineering and |
18 | | design study) shall be expressed in nominal dollars as |
19 | | of the date that the quote is prepared and shall |
20 | | include taxes, insurance, and other owner's costs, and |
21 | | an assumed escalation in materials and labor beyond the |
22 | | date as of which the operating and maintenance cost |
23 | | quote is expressed. |
24 | | (D) The facility cost report shall also include an |
25 | | analysis of the initial clean coal facility's ability |
26 | | to deliver power and energy into the applicable |
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1 | | regional transmission organization markets and an |
2 | | analysis of the expected capacity factor for the |
3 | | initial clean coal facility. |
4 | | (E) Amounts paid to third parties unrelated to the |
5 | | owner or owners of the initial clean coal facility to |
6 | | prepare the core plant construction cost quote, |
7 | | including the front end engineering and design study, |
8 | | and the operating and maintenance cost quote will be |
9 | | reimbursed through Coal Development Bonds. |
10 | | (5) Re-powering and retrofitting coal-fired power |
11 | | plants previously owned by Illinois utilities to qualify as |
12 | | clean coal facilities. During the 2009 procurement |
13 | | planning process and thereafter, the Agency and the |
14 | | Commission shall consider sourcing agreements covering |
15 | | electricity generated by power plants that were previously |
16 | | owned by Illinois utilities and that have been or will be |
17 | | converted into clean coal facilities, as defined by Section |
18 | | 1-10 of this Act. Pursuant to such procurement planning |
19 | | process, the owners of such facilities may propose to the |
20 | | Agency sourcing agreements with utilities and alternative |
21 | | retail electric suppliers required to comply with |
22 | | subsection (d) of this Section and item (5) of subsection |
23 | | (d) of Section 16-115 of the Public Utilities Act, covering |
24 | | electricity generated by such facilities. In the case of |
25 | | sourcing agreements that are power purchase agreements, |
26 | | the contract price for electricity sales shall be |
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1 | | established on a cost of service basis. In the case of |
2 | | sourcing agreements that are contracts for differences, |
3 | | the contract price from which the reference price is |
4 | | subtracted shall be established on a cost of service basis. |
5 | | The Agency and the Commission may approve any such utility |
6 | | sourcing agreements that do not exceed cost-based |
7 | | benchmarks developed by the procurement administrator, in |
8 | | consultation with the Commission staff, Agency staff and |
9 | | the procurement monitor, subject to Commission review and |
10 | | approval. The Commission shall have authority to inspect |
11 | | all books and records associated with these clean coal |
12 | | facilities during the term of any such contract. |
13 | | (6) Costs incurred under this subsection (d) or |
14 | | pursuant to a contract entered into under this subsection |
15 | | (d) shall be deemed prudently incurred and reasonable in |
16 | | amount and the electric utility shall be entitled to full |
17 | | cost recovery pursuant to the tariffs filed with the |
18 | | Commission. |
19 | | (d-5) Zero emission standard. |
20 | | (1) Beginning with the delivery year commencing on June |
21 | | 1, 2017, the Agency shall, for electric utilities that |
22 | | serve at least 100,000 retail customers in this State, |
23 | | procure contracts with zero emission facilities that are |
24 | | reasonably capable of generating cost-effective zero |
25 | | emission credits in an amount approximately equal to 16% of |
26 | | the actual amount of electricity delivered by each electric |
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1 | | utility to retail customers in the State during calendar |
2 | | year 2014. For an electric utility serving fewer than |
3 | | 100,000 retail customers in this State that requested, |
4 | | under Section 16-111.5 of the Public Utilities Act, that |
5 | | the Agency procure power and energy for all or a portion of |
6 | | the utility's Illinois load for the delivery year |
7 | | commencing June 1, 2016, the Agency shall procure contracts |
8 | | with zero emission facilities that are reasonably capable |
9 | | of generating cost-effective zero emission credits in an |
10 | | amount approximately equal to 16% of the portion of power |
11 | | and energy to be procured by the Agency for the utility. |
12 | | The duration of the contracts procured under this |
13 | | subsection (d-5) shall be for a term of 10 years ending May |
14 | | 31, 2027. The quantity of zero emission credits to be |
15 | | procured under the contracts shall be all of the zero |
16 | | emission credits generated by the zero emission facility in |
17 | | each delivery year; however, if the zero emission facility |
18 | | is owned by more than one entity, then the quantity of zero |
19 | | emission credits to be procured under the contracts shall |
20 | | be the amount of zero emission credits that are generated |
21 | | from the portion of the zero emission facility that is |
22 | | owned by the winning supplier. |
23 | | The 16% value identified in this paragraph (1) is the |
24 | | average of the percentage targets in subparagraph (B) of |
25 | | paragraph (1) of subsection (c) of this Section 1-75 of |
26 | | this Act for the 5 delivery years beginning June 1, 2017. |
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1 | | The procurement process shall be subject to the |
2 | | following provisions: |
3 | | (A) Those zero emission facilities that intend to |
4 | | participate in the procurement shall submit to the |
5 | | Agency the following eligibility information for each |
6 | | zero emission facility on or before the date |
7 | | established by the Agency: |
8 | | (i) the in-service date and remaining useful |
9 | | life of the zero emission facility; |
10 | | (ii) the amount of power generated annually |
11 | | for each of the years 2005 through 2015, and the |
12 | | projected zero emission credits to be generated |
13 | | over the remaining useful life of the zero emission |
14 | | facility, which shall be used to determine the |
15 | | capability of each facility; |
16 | | (iii) the annual zero emission facility cost |
17 | | projections, expressed on a per megawatthour |
18 | | basis, over the next 6 delivery years, which shall |
19 | | include the following: operation and maintenance |
20 | | expenses; fully allocated overhead costs, which |
21 | | shall be allocated using the methodology developed |
22 | | by the Institute for Nuclear Power Operations; |
23 | | fuel expenditures; non-fuel capital expenditures; |
24 | | spent fuel expenditures; a return on working |
25 | | capital; the cost of operational and market risks |
26 | | that could be avoided by ceasing operation; and any |
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1 | | other costs necessary for continued operations, |
2 | | provided that "necessary" means, for purposes of |
3 | | this item (iii), that the costs could reasonably be |
4 | | avoided only by ceasing operations of the zero |
5 | | emission facility; and |
6 | | (iv) a commitment to continue operating, for |
7 | | the duration of the contract or contracts executed |
8 | | under the procurement held under this subsection |
9 | | (d-5), the zero emission facility that produces |
10 | | the zero emission credits to be procured in the |
11 | | procurement. |
12 | | The information described in item (iii) of this |
13 | | subparagraph (A) may be submitted on a confidential |
14 | | basis and shall be treated and maintained by the |
15 | | Agency, the procurement administrator, and the |
16 | | Commission as confidential and proprietary and exempt |
17 | | from disclosure under subparagraphs (a) and (g) of |
18 | | paragraph (1) of Section 7 of the Freedom of |
19 | | Information Act. The Office of Attorney General shall |
20 | | have access to, and maintain the confidentiality of, |
21 | | such information pursuant to Section 6.5 of the |
22 | | Attorney General Act. |
23 | | (B) The price for each zero emission credit |
24 | | procured under this subsection (d-5) for each delivery |
25 | | year shall be in an amount that equals the Social Cost |
26 | | of Carbon, expressed on a price per megawatthour basis. |
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1 | | However, to ensure that the procurement remains |
2 | | affordable to retail customers in this State if |
3 | | electricity prices increase, the price in an |
4 | | applicable delivery year shall be reduced below the |
5 | | Social Cost of Carbon by the amount ("Price |
6 | | Adjustment") by which the market price index for the |
7 | | applicable delivery year exceeds the baseline market |
8 | | price index for the consecutive 12-month period ending |
9 | | May 31, 2016. If the Price Adjustment is greater than |
10 | | or equal to the Social Cost of Carbon in an applicable |
11 | | delivery year, then no payments shall be due in that |
12 | | delivery year. The components of this calculation are |
13 | | defined as follows: |
14 | | (i) Social Cost of Carbon: The Social Cost of |
15 | | Carbon is $16.50 per megawatthour, which is based |
16 | | on the U.S. Interagency Working Group on Social |
17 | | Cost of Carbon's price in the August 2016 Technical |
18 | | Update using a 3% discount rate, adjusted for |
19 | | inflation for each year of the program. Beginning |
20 | | with the delivery year commencing June 1, 2023, the |
21 | | price per megawatthour shall increase by $1 per |
22 | | megawatthour, and continue to increase by an |
23 | | additional $1 per megawatthour each delivery year |
24 | | thereafter. |
25 | | (ii) Baseline market price index: The baseline |
26 | | market price index for the consecutive 12-month |
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1 | | period ending May 31, 2016 is $31.40 per |
2 | | megawatthour, which is based on the sum of (aa) the |
3 | | average day-ahead energy price across all hours of |
4 | | such 12-month period at the PJM Interconnection |
5 | | LLC Northern Illinois Hub, (bb) 50% multiplied by |
6 | | the Base Residual Auction, or its successor, |
7 | | capacity price for the rest of the RTO zone group |
8 | | determined by PJM Interconnection LLC, divided by |
9 | | 24 hours per day, and (cc) 50% multiplied by the |
10 | | Planning Resource Auction, or its successor, |
11 | | capacity price for Zone 4 determined by the |
12 | | Midcontinent Independent System Operator, Inc., |
13 | | divided by 24 hours per day. |
14 | | (iii) Market price index: The market price |
15 | | index for a delivery year shall be the sum of |
16 | | projected energy prices and projected capacity |
17 | | prices determined as follows: |
18 | | (aa) Projected energy prices: the |
19 | | projected energy prices for the applicable |
20 | | delivery year shall be calculated once for the |
21 | | year using the forward market price for the PJM |
22 | | Interconnection, LLC Northern Illinois Hub. |
23 | | The forward market price shall be calculated as |
24 | | follows: the energy forward prices for each |
25 | | month of the applicable delivery year averaged |
26 | | for each trade date during the calendar year |
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1 | | immediately preceding that delivery year to |
2 | | produce a single energy forward price for the |
3 | | delivery year. The forward market price |
4 | | calculation shall use data published by the |
5 | | Intercontinental Exchange, or its successor. |
6 | | (bb) Projected capacity prices: |
7 | | (I) For the delivery years commencing |
8 | | June 1, 2017, June 1, 2018, and June 1, |
9 | | 2019, the projected capacity price shall |
10 | | be equal to the sum of (1) 50% multiplied |
11 | | by the Base Residual Auction, or its |
12 | | successor, price for the rest of the RTO |
13 | | zone group as determined by PJM |
14 | | Interconnection LLC, divided by 24 hours |
15 | | per day and, (2) 50% multiplied by the |
16 | | resource auction price determined in the |
17 | | resource auction administered by the |
18 | | Midcontinent Independent System Operator, |
19 | | Inc., in which the largest percentage of |
20 | | load cleared for Local Resource Zone 4, |
21 | | divided by 24 hours per day, and where such |
22 | | price is determined by the Midcontinent |
23 | | Independent System Operator, Inc. |
24 | | (II) For the delivery year commencing |
25 | | June 1, 2020, and each year thereafter, the |
26 | | projected capacity price shall be equal to |
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1 | | the sum of (1) 50% multiplied by the Base |
2 | | Residual Auction, or its successor, price |
3 | | for the ComEd zone as determined by PJM |
4 | | Interconnection LLC, divided by 24 hours |
5 | | per day, and (2) 50% multiplied by the |
6 | | resource auction price determined in the |
7 | | resource auction administered by the |
8 | | Midcontinent Independent System Operator, |
9 | | Inc., in which the largest percentage of |
10 | | load cleared for Local Resource Zone 4, |
11 | | divided by 24 hours per day, and where such |
12 | | price is determined by the Midcontinent |
13 | | Independent System Operator, Inc. |
14 | | For purposes of this subsection (d-5): |
15 | | "Rest of the RTO" and "ComEd Zone" shall have |
16 | | the meaning ascribed to them by PJM |
17 | | Interconnection, LLC. |
18 | | "RTO" means regional transmission |
19 | | organization. |
20 | | (C) No later than 45 days after June 1, 2017 (the |
21 | | effective date of Public Act 99-906), the Agency shall |
22 | | publish its proposed zero emission standard |
23 | | procurement plan. The plan shall be consistent with the |
24 | | provisions of this paragraph (1) and shall provide that |
25 | | winning bids shall be selected based on public interest |
26 | | criteria that include, but are not limited to, |
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1 | | minimizing carbon dioxide emissions that result from |
2 | | electricity consumed in Illinois and minimizing sulfur |
3 | | dioxide, nitrogen oxide, and particulate matter |
4 | | emissions that adversely affect the citizens of this |
5 | | State. In particular, the selection of winning bids |
6 | | shall take into account the incremental environmental |
7 | | benefits resulting from the procurement, such as any |
8 | | existing environmental benefits that are preserved by |
9 | | the procurements held under Public Act 99-906 and would |
10 | | cease to exist if the procurements were not held, |
11 | | including the preservation of zero emission |
12 | | facilities. The plan shall also describe in detail how |
13 | | each public interest factor shall be considered and |
14 | | weighted in the bid selection process to ensure that |
15 | | the public interest criteria are applied to the |
16 | | procurement and given full effect. |
17 | | For purposes of developing the plan, the Agency |
18 | | shall consider any reports issued by a State agency, |
19 | | board, or commission under House Resolution 1146 of the |
20 | | 98th General Assembly and paragraph (4) of subsection |
21 | | (d) of this Section 1-75 of this Act , as well as |
22 | | publicly available analyses and studies performed by |
23 | | or for regional transmission organizations that serve |
24 | | the State and their independent market monitors. |
25 | | Upon publishing of the zero emission standard |
26 | | procurement plan, copies of the plan shall be posted |
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1 | | and made publicly available on the Agency's website. |
2 | | All interested parties shall have 10 days following the |
3 | | date of posting to provide comment to the Agency on the |
4 | | plan. All comments shall be posted to the Agency's |
5 | | website. Following the end of the comment period, but |
6 | | no more than 60 days later than June 1, 2017 (the |
7 | | effective date of Public Act 99-906), the Agency shall |
8 | | revise the plan as necessary based on the comments |
9 | | received and file its zero emission standard |
10 | | procurement plan with the Commission. |
11 | | If the Commission determines that the plan will |
12 | | result in the procurement of cost-effective zero |
13 | | emission credits, then the Commission shall, after |
14 | | notice and hearing, but no later than 45 days after the |
15 | | Agency filed the plan, approve the plan or approve with |
16 | | modification. For purposes of this subsection (d-5), |
17 | | "cost effective" means the projected costs of |
18 | | procuring zero emission credits from zero emission |
19 | | facilities do not cause the limit stated in paragraph |
20 | | (2) of this subsection to be exceeded. |
21 | | (C-5) As part of the Commission's review and |
22 | | acceptance or rejection of the procurement results, |
23 | | the Commission shall, in its public notice of |
24 | | successful bidders: |
25 | | (i) identify how the winning bids satisfy the |
26 | | public interest criteria described in subparagraph |
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1 | | (C) of this paragraph (1) of minimizing carbon |
2 | | dioxide emissions that result from electricity |
3 | | consumed in Illinois and minimizing sulfur |
4 | | dioxide, nitrogen oxide, and particulate matter |
5 | | emissions that adversely affect the citizens of |
6 | | this State; |
7 | | (ii) specifically address how the selection of |
8 | | winning bids takes into account the incremental |
9 | | environmental benefits resulting from the |
10 | | procurement, including any existing environmental |
11 | | benefits that are preserved by the procurements |
12 | | held under Public Act 99-906 and would have ceased |
13 | | to exist if the procurements had not been held, |
14 | | such as the preservation of zero emission |
15 | | facilities; |
16 | | (iii) quantify the environmental benefit of |
17 | | preserving the resources identified in item (ii) |
18 | | of this subparagraph (C-5), including the |
19 | | following: |
20 | | (aa) the value of avoided greenhouse gas |
21 | | emissions measured as the product of the zero |
22 | | emission facilities' output over the contract |
23 | | term multiplied by the U.S. Environmental |
24 | | Protection Agency eGrid subregion carbon |
25 | | dioxide emission rate and the U.S. Interagency |
26 | | Working Group on Social Cost of Carbon's price |
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1 | | in the August 2016 Technical Update using a 3% |
2 | | discount rate, adjusted for inflation for each |
3 | | delivery year; and |
4 | | (bb) the costs of replacement with other |
5 | | zero carbon dioxide resources, including wind |
6 | | and photovoltaic, based upon the simple |
7 | | average of the following: |
8 | | (I) the price, or if there is more than |
9 | | one price, the average of the prices, paid |
10 | | for renewable energy credits from new |
11 | | utility-scale wind projects in the |
12 | | procurement events specified in item (i) |
13 | | of subparagraph (G) of paragraph (1) of |
14 | | subsection (c) of this Section 1-75 of this |
15 | | Act ; and |
16 | | (II) the price, or if there is more |
17 | | than one price, the average of the prices, |
18 | | paid for renewable energy credits from new |
19 | | utility-scale solar projects and |
20 | | brownfield site photovoltaic projects in |
21 | | the procurement events specified in item |
22 | | (ii) of subparagraph (G) of paragraph (1) |
23 | | of subsection (c) of this Section 1-75 of |
24 | | this Act and, after January 1, 2015, |
25 | | renewable energy credits from photovoltaic |
26 | | distributed generation projects in |
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1 | | procurement events held under subsection |
2 | | (c) of this Section 1-75 of this Act . |
3 | | Each utility shall enter into binding contractual |
4 | | arrangements with the winning suppliers. |
5 | | The procurement described in this subsection |
6 | | (d-5), including, but not limited to, the execution of |
7 | | all contracts procured, shall be completed no later |
8 | | than May 10, 2017. Based on the effective date of |
9 | | Public Act 99-906, the Agency and Commission may, as |
10 | | appropriate, modify the various dates and timelines |
11 | | under this subparagraph and subparagraphs (C) and (D) |
12 | | of this paragraph (1). The procurement and plan |
13 | | approval processes required by this subsection (d-5) |
14 | | shall be conducted in conjunction with the procurement |
15 | | and plan approval processes required by subsection (c) |
16 | | of this Section and Section 16-111.5 of the Public |
17 | | Utilities Act, to the extent practicable. |
18 | | Notwithstanding whether a procurement event is |
19 | | conducted under Section 16-111.5 of the Public |
20 | | Utilities Act, the Agency shall immediately initiate a |
21 | | procurement process on June 1, 2017 (the effective date |
22 | | of Public Act 99-906). |
23 | | (D) Following the procurement event described in |
24 | | this paragraph (1) and consistent with subparagraph |
25 | | (B) of this paragraph (1), the Agency shall calculate |
26 | | the payments to be made under each contract for the |
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1 | | next delivery year based on the market price index for |
2 | | that delivery year. The Agency shall publish the |
3 | | payment calculations no later than May 25, 2017 and |
4 | | every May 25 thereafter. |
5 | | (E) Notwithstanding the requirements of this |
6 | | subsection (d-5), the contracts executed under this |
7 | | subsection (d-5) shall provide that the zero emission |
8 | | facility may, as applicable, suspend or terminate |
9 | | performance under the contracts in the following |
10 | | instances: |
11 | | (i) A zero emission facility shall be excused |
12 | | from its performance under the contract for any |
13 | | cause beyond the control of the resource, |
14 | | including, but not restricted to, acts of God, |
15 | | flood, drought, earthquake, storm, fire, |
16 | | lightning, epidemic, war, riot, civil disturbance |
17 | | or disobedience, labor dispute, labor or material |
18 | | shortage, sabotage, acts of public enemy, |
19 | | explosions, orders, regulations or restrictions |
20 | | imposed by governmental, military, or lawfully |
21 | | established civilian authorities, which, in any of |
22 | | the foregoing cases, by exercise of commercially |
23 | | reasonable efforts the zero emission facility |
24 | | could not reasonably have been expected to avoid, |
25 | | and which, by the exercise of commercially |
26 | | reasonable efforts, it has been unable to |
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1 | | overcome. In such event, the zero emission |
2 | | facility shall be excused from performance for the |
3 | | duration of the event, including, but not limited |
4 | | to, delivery of zero emission credits, and no |
5 | | payment shall be due to the zero emission facility |
6 | | during the duration of the event. |
7 | | (ii) A zero emission facility shall be |
8 | | permitted to terminate the contract if legislation |
9 | | is enacted into law by the General Assembly that |
10 | | imposes or authorizes a new tax, special |
11 | | assessment, or fee on the generation of |
12 | | electricity, the ownership or leasehold of a |
13 | | generating unit, or the privilege or occupation of |
14 | | such generation, ownership, or leasehold of |
15 | | generation units by a zero emission facility. |
16 | | However, the provisions of this item (ii) do not |
17 | | apply to any generally applicable tax, special |
18 | | assessment or fee, or requirements imposed by |
19 | | federal law. |
20 | | (iii) A zero emission facility shall be |
21 | | permitted to terminate the contract in the event |
22 | | that the resource requires capital expenditures in |
23 | | excess of $40,000,000 that were neither known nor |
24 | | reasonably foreseeable at the time it executed the |
25 | | contract and that a prudent owner or operator of |
26 | | such resource would not undertake. |
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1 | | (iv) A zero emission facility shall be |
2 | | permitted to terminate the contract in the event |
3 | | the Nuclear Regulatory Commission terminates the |
4 | | resource's license. |
5 | | (F) If the zero emission facility elects to |
6 | | terminate a contract under this subparagraph (E ) , of |
7 | | this paragraph (1), then the Commission shall reopen |
8 | | the docket in which the Commission approved the zero |
9 | | emission standard procurement plan under subparagraph |
10 | | (C) of this paragraph (1) and, after notice and |
11 | | hearing, enter an order acknowledging the contract |
12 | | termination election if such termination is consistent |
13 | | with the provisions of this subsection (d-5). |
14 | | (2) For purposes of this subsection (d-5), the amount |
15 | | paid per kilowatthour means the total amount paid for |
16 | | electric service expressed on a per kilowatthour basis. For |
17 | | purposes of this subsection (d-5), the total amount paid |
18 | | for electric service includes, without limitation, amounts |
19 | | paid for supply, transmission, distribution, surcharges, |
20 | | and add-on taxes. |
21 | | Notwithstanding the requirements of this subsection |
22 | | (d-5), the contracts executed under this subsection (d-5) |
23 | | shall provide that the total of zero emission credits |
24 | | procured under a procurement plan shall be subject to the |
25 | | limitations of this paragraph (2). For each delivery year, |
26 | | the contractual volume receiving payments in such year |
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1 | | shall be reduced for all retail customers based on the |
2 | | amount necessary to limit the net increase that delivery |
3 | | year to the costs of those credits included in the amounts |
4 | | paid by eligible retail customers in connection with |
5 | | electric service to no more than 1.65% of the amount paid |
6 | | per kilowatthour by eligible retail customers during the |
7 | | year ending May 31, 2009. The result of this computation |
8 | | shall apply to and reduce the procurement for all retail |
9 | | customers, and all those customers shall pay the same |
10 | | single, uniform cents per kilowatthour charge under |
11 | | subsection (k) of Section 16-108 of the Public Utilities |
12 | | Act. To arrive at a maximum dollar amount of zero emission |
13 | | credits to be paid for the particular delivery year, the |
14 | | resulting per kilowatthour amount shall be applied to the |
15 | | actual amount of kilowatthours of electricity delivered by |
16 | | the electric utility in the delivery year immediately prior |
17 | | to the procurement, to all retail customers in its service |
18 | | territory. Unpaid contractual volume for any delivery year |
19 | | shall be paid in any subsequent delivery year in which such |
20 | | payments can be made without exceeding the amount specified |
21 | | in this paragraph (2). The calculations required by this |
22 | | paragraph (2) shall be made only once for each procurement |
23 | | plan year. Once the determination as to the amount of zero |
24 | | emission credits to be paid is made based on the |
25 | | calculations set forth in this paragraph (2), no subsequent |
26 | | rate impact determinations shall be made and no adjustments |
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1 | | to those contract amounts shall be allowed. All costs |
2 | | incurred under those contracts and in implementing this |
3 | | subsection (d-5) shall be recovered by the electric utility |
4 | | as provided in this Section. |
5 | | No later than June 30, 2019, the Commission shall |
6 | | review the limitation on the amount of zero emission |
7 | | credits procured under this subsection (d-5) and report to |
8 | | the General Assembly its findings as to whether that |
9 | | limitation unduly constrains the procurement of |
10 | | cost-effective zero emission credits. |
11 | | (3) Six years after the execution of a contract under |
12 | | this subsection (d-5), the Agency shall determine whether |
13 | | the actual zero emission credit payments received by the |
14 | | supplier over the 6-year period exceed the Average ZEC |
15 | | Payment. In addition, at the end of the term of a contract |
16 | | executed under this subsection (d-5), or at the time, if |
17 | | any, a zero emission facility's contract is terminated |
18 | | under subparagraph (E) of paragraph (1) of this subsection |
19 | | (d-5), then the Agency shall determine whether the actual |
20 | | zero emission credit payments received by the supplier over |
21 | | the term of the contract exceed the Average ZEC Payment, |
22 | | after taking into account any amounts previously credited |
23 | | back to the utility under this paragraph (3). If the Agency |
24 | | determines that the actual zero emission credit payments |
25 | | received by the supplier over the relevant period exceed |
26 | | the Average ZEC Payment, then the supplier shall credit the |
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1 | | difference back to the utility. The amount of the credit |
2 | | shall be remitted to the applicable electric utility no |
3 | | later than 120 days after the Agency's determination, which |
4 | | the utility shall reflect as a credit on its retail |
5 | | customer bills as soon as practicable; however, the credit |
6 | | remitted to the utility shall not exceed the total amount |
7 | | of payments received by the facility under its contract. |
8 | | For purposes of this Section, the Average ZEC Payment |
9 | | shall be calculated by multiplying the quantity of zero |
10 | | emission credits delivered under the contract times the |
11 | | average contract price. The average contract price shall be |
12 | | determined by subtracting the amount calculated under |
13 | | subparagraph (B) of this paragraph (3) from the amount |
14 | | calculated under subparagraph (A) of this paragraph (3), as |
15 | | follows: |
16 | | (A) The average of the Social Cost of Carbon, as |
17 | | defined in subparagraph (B) of paragraph (1) of this |
18 | | subsection (d-5), during the term of the contract. |
19 | | (B) The average of the market price indices, as |
20 | | defined in subparagraph (B) of paragraph (1) of this |
21 | | subsection (d-5), during the term of the contract, |
22 | | minus the baseline market price index, as defined in |
23 | | subparagraph (B) of paragraph (1) of this subsection |
24 | | (d-5). |
25 | | If the subtraction yields a negative number, then the |
26 | | Average ZEC Payment shall be zero. |
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1 | | (4) Cost-effective zero emission credits procured from |
2 | | zero emission facilities shall satisfy the applicable |
3 | | definitions set forth in Section 1-10 of this Act. |
4 | | (5) The electric utility shall retire all zero emission |
5 | | credits used to comply with the requirements of this |
6 | | subsection (d-5). |
7 | | (6) Electric utilities shall be entitled to recover all |
8 | | of the costs associated with the procurement of zero |
9 | | emission credits through an automatic adjustment clause |
10 | | tariff in accordance with subsection (k) and (m) of Section |
11 | | 16-108 of the Public Utilities Act, and the contracts |
12 | | executed under this subsection (d-5) shall provide that the |
13 | | utilities' payment obligations under such contracts shall |
14 | | be reduced if an adjustment is required under subsection |
15 | | (m) of Section 16-108 of the Public Utilities Act. |
16 | | (7) This subsection (d-5) shall become inoperative on |
17 | | January 1, 2028. |
18 | | (e) The draft procurement plans are subject to public |
19 | | comment, as required by Section 16-111.5 of the Public |
20 | | Utilities Act. |
21 | | (f) The Agency shall submit the final procurement plan to |
22 | | the Commission. The Agency shall revise a procurement plan if |
23 | | the Commission determines that it does not meet the standards |
24 | | set forth in Section 16-111.5 of the Public Utilities Act. |
25 | | (g) The Agency shall assess fees to each affected utility |
26 | | to recover the costs incurred in preparation of the annual |
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1 | | procurement plan for the utility. |
2 | | (h) The Agency shall assess fees to each bidder to recover |
3 | | the costs incurred in connection with a competitive procurement |
4 | | process.
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5 | | (i) A renewable energy credit, carbon emission credit, or |
6 | | zero emission credit can only be used once to comply with a |
7 | | single portfolio or other standard as set forth in subsection |
8 | | (c), subsection (d), or subsection (d-5) of this Section, |
9 | | respectively. A renewable energy credit, carbon emission |
10 | | credit, or zero emission credit cannot be used to satisfy the |
11 | | requirements of more than one standard. If more than one type |
12 | | of credit is issued for the same megawatt hour of energy, only |
13 | | one credit can be used to satisfy the requirements of a single |
14 | | standard. After such use, the credit must be retired together |
15 | | with any other credits issued for the same megawatt hour of |
16 | | energy. |
17 | | (j) Bundled procurement. |
18 | | (1) Beginning with the energy, capacity and renewable |
19 | | energy credits to be delivered in the delivery year |
20 | | commencing on June 1, 2021, the Agency shall procure |
21 | | cost-effective, long-term bundled contracts for energy |
22 | | supply, renewable energy credits from new renewable energy |
23 | | projects as defined in subparagraph (P) of subsection (c) |
24 | | of this Section, and, subject to the requirements of |
25 | | subsection (k) of this Section, capacity, in accordance |
26 | | with the requirements of Section 16-111.5 of the Public |
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1 | | Utilities Act for the eligible retail customers of electric |
2 | | utilities that on December 31, 2005 provided electric |
3 | | service to at least 100,000 customers in Illinois. At a |
4 | | minimum, energy supply procured by the Agency through new |
5 | | long-term bundled contracts shall be: |
6 | | (A) 3,000,000 megawatt-hours and associated |
7 | | renewable energy credits and, subject to the |
8 | | requirements of subsection (k) of this Section, |
9 | | capacity from new wind and solar projects for the |
10 | | delivery year beginning June 1, 2021. |
11 | | (B) 6,000,000 megawatt-hours and associated |
12 | | renewable energy credits and, subject to the |
13 | | requirements of subsection (k) of this Section, |
14 | | capacity from new wind and solar projects for the |
15 | | delivery year beginning June 1, 2022. |
16 | | (C) 9,000,000 megawatt-hours and associated |
17 | | renewable energy credits and, subject to the |
18 | | requirements of subsection (k) of this Section, |
19 | | capacity from new wind and solar projects for the |
20 | | delivery year beginning June 1, 2023. |
21 | | (D) 12,000,000 megawatt-hours and associated |
22 | | renewable energy credits and, subject to the |
23 | | requirements of subsection (k) of this Section, |
24 | | capacity from new wind and solar projects for the |
25 | | delivery year beginning June 1, 2024. |
26 | | (E) 15,000,000 megawatt-hours and associated |
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1 | | renewable energy credits and, subject to the |
2 | | requirements of subsection (k) of this Section, |
3 | | capacity from new wind and solar projects for the |
4 | | delivery year beginning June 1, 2025. |
5 | | (F) 18,000,000 megawatt-hours and associated |
6 | | renewable energy credits and, subject to the |
7 | | requirements of subsection (k) of this Section, |
8 | | capacity from new wind and solar projects for the |
9 | | delivery year beginning June 1, 2026. |
10 | | (G) 21,000,000 megawatt-hours and associated |
11 | | renewable energy credits and, subject to the |
12 | | requirements of subsection (k) of this Section, |
13 | | capacity from new wind and solar projects for the |
14 | | delivery year beginning June 1, 2027. |
15 | | (H) 24,000,000 megawatt-hours and associated |
16 | | renewable energy credits and, subject to the |
17 | | requirements of subsection (k) of this Section, |
18 | | capacity from new wind and solar projects for the |
19 | | delivery year beginning June 1, 2028 and thereafter. |
20 | | (2) Long-term bundled contracts as described in this |
21 | | subsection shall refer to contracts that contain no less |
22 | | than a 15-year period. |
23 | | (3) Long-term bundled contracts shall only be awarded |
24 | | for new renewable energy projects as defined in |
25 | | subparagraphs (C) and (P) of subsection (c) of this |
26 | | Section. Nothing in this Section is intended to preclude |
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1 | | distributed generation from participating. |
2 | | (4) Long-term bundled contracts as described in this |
3 | | subsection may include procurements that include energy |
4 | | supply plus renewable energy credits, procurements that |
5 | | include capacity, subject to the requirements of |
6 | | subsection (k) of this Section, plus renewable energy |
7 | | credits, or procurements that include energy supply plus |
8 | | capacity plus renewable energy credits. |
9 | | (5) Long-term bundled contracts as described in this |
10 | | subsection shall be procured in a procurement event prior |
11 | | to the scheduled Reliability Pricing Model Auctions of the |
12 | | PJM Interconnection LLC and the Planning Resource Actions |
13 | | of the Midcontinent Independent System Operator. |
14 | | (k) Carbon-free resources. |
15 | | (1) Carbon-free capacity. Beginning with the |
16 | | procurement for the delivery year commencing June 1, 2022, |
17 | | if possible, but no later than for the delivery year |
18 | | commencing June 1, 2023, the Agency shall develop a plan |
19 | | and conduct a procurement of capacity from qualified |
20 | | resources as part of its procurement plan described in |
21 | | Section 16-111.5 of the Public Utilities Act with the goals |
22 | | of reducing pollution from the power sector, lowering |
23 | | consumer costs, and creating investment opportunities for |
24 | | new renewable resources. For the purposes of this |
25 | | subsection, "qualified resources" means (A) energy |
26 | | efficiency measures that are implemented pursuant to plans |
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1 | | approved by the Commission under Sections 8-103, 8-103B, |
2 | | and 8-104 of the Public Utilities Act; (B) renewable energy |
3 | | resources; (C) zero emission facilities; and (D) resources |
4 | | as part of a clean peak program under subsection (l) of |
5 | | this Section, subject to the requirements in the open |
6 | | access tariff and manuals of PJM Interconnection and |
7 | | approved by the Federal Energy Regulatory Commission. The |
8 | | capacity portion of qualified resources shall be counted |
9 | | toward fulfillment of capacity obligations within the |
10 | | local delivery area of an electric utility serving more |
11 | | than 3,000,000 retail customers that is a member of PJM |
12 | | Interconnection LLC, as defined in the open access tariff |
13 | | and manuals of PJM Interconnection and approved by the |
14 | | Federal Energy Regulatory Commission, as applicable. The |
15 | | Agency shall calculate the eligible capacity contribution |
16 | | of qualified resources procured, and match it to an |
17 | | equivalent megawatt quantity or portion of capacity |
18 | | obligation of load within the local delivery zone. The |
19 | | resulting capacity and load obligation shall be reported in |
20 | | accordance with the applicable provisions of the Open |
21 | | Access Transmission Tariff and manuals of PJM |
22 | | Interconnection LLC. |
23 | | (2) Carbon-free supply. Beginning with the delivery |
24 | | year commencing June 1, 2021, the Agency shall ensure its |
25 | | procurement of energy supply, in accordance with the |
26 | | requirements of Section 16-111.5 of the Public Utilities |
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1 | | Act for the eligible retail customers of electric utilities |
2 | | that on December 31, 2005 provided electric service to at |
3 | | least 100,000 customers in Illinois, achieves a |
4 | | progressive annual ramp down to an emission rate of zero |
5 | | pounds of carbon dioxide emissions per megawatt-hour by May |
6 | | 31, 2030. At a minimum, energy supply procured by the |
7 | | Agency through new long-term bundled contracts shall be: |
8 | | (A) 1,000 pounds per megawatt-hour of carbon |
9 | | dioxide emissions per megawatt-hour for the delivery |
10 | | year beginning June 1, 2021. |
11 | | (B) 500 pounds per megawatt-hour of carbon dioxide |
12 | | emissions per megawatt-hour for the delivery year |
13 | | beginning June 1, 2026. |
14 | | (C) zero pounds per megawatt-hour of carbon |
15 | | dioxide emissions per megawatt-hour for the delivery |
16 | | year beginning June 1, 2030 and thereafter. |
17 | | (l) Clean Peak Program. |
18 | | (1) In this subsection: |
19 | | "Energy storage response threshold level" means a |
20 | | level, in megawatts, for the designated locational |
21 | | delivery area system-wide demand at which energy storage |
22 | | resources must begin providing demand reduction at its |
23 | | committed level. The energy storage response threshold |
24 | | level shall be set by the Agency to coincide with the top |
25 | | 100 hours of demand in the designated zone, accounting for |
26 | | seasonal variability in capacity needs and any capacity |
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1 | | performance requirements included in the Open Access |
2 | | Transmission Tariff and manuals of PJM Interconnection, |
3 | | LLC. |
4 | | "Demand response threshold level" means a level, in |
5 | | megawatts, of the locational delivery area system-wide |
6 | | demand at which demand response resources must begin |
7 | | providing demand reduction at its committed demand |
8 | | response threshold level. The demand response threshold |
9 | | level shall be set by the Agency to coincide with the top |
10 | | 100 hours of demand in the designated zone, accounting for |
11 | | seasonal variability in capacity needs and any capacity |
12 | | performance requirements included in the Open Access |
13 | | Transmission Tariff and manuals of PJM Interconnection |
14 | | LLC. |
15 | | (2) The Agency shall develop a Clean Peak Program plan |
16 | | that shall include programs and competitive procurement |
17 | | events necessary to meet the goals set forth in this |
18 | | subsection (l). Within 90 days after the effective date of |
19 | | this amendatory Act of the 101st General Assembly, the |
20 | | Agency shall release for comment an initial Clean Peak |
21 | | Program plan. The Clean Peak Program plan shall be subject |
22 | | to review and approval by the Commission under Section |
23 | | 16-111.5 of the Public Utilities Act. The Agency shall |
24 | | review and update on an annual basis a Clean Peak Program |
25 | | plan which shall be reviewed and approved by the Commission |
26 | | in conjunction with the procurement plan under Section |
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1 | | 16-111.5 of the Public Utilities Act to the extent |
2 | | practicable to minimize administrative expense. |
3 | | (3) The Clean Peak Program shall include progressive |
4 | | annual goals and efforts to achieve a 15% reduction in the |
5 | | Capacity and Network Service Peak Load Contributions in the |
6 | | Commission zone, as determined by PJM Interconnection LLC |
7 | | in its Open Access Transmission Tariff, by the beginning of |
8 | | the delivery year commencing June 1, 2023, and each year |
9 | | thereafter, based on the measured Capacity and Network |
10 | | Service Peak Load Contribution of the designated zone for |
11 | | the delivery year commencing June 1, 2017. |
12 | | (4) The Clean Peak Program shall consist of the |
13 | | following elements: |
14 | | (A) Energy storage resources that commit to |
15 | | achieve a reduction in electricity demand in the |
16 | | designated zone, in megawatts based on seasonal |
17 | | capability, when the electricity demand of the |
18 | | designated zone reaches an energy storage response |
19 | | threshold level, in megawatts. |
20 | | (B) Energy storage resources, co-located with and |
21 | | that are energized primarily from wind and solar |
22 | | projects, that commit to achieve a reduction in |
23 | | electricity demand in the designated zone, in |
24 | | megawatts based on seasonal capability, when the |
25 | | electricity demand of the designated zone reaches an |
26 | | energy storage response threshold level, in megawatts. |
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1 | | (C) Demand response resources, not including |
2 | | generators powered by diesel fuel or natural gas, that |
3 | | commit to achieve a reduction in electricity demand in |
4 | | the designated zone, in megawatts based on seasonal |
5 | | capability, when the electricity demand of the |
6 | | designated zone reaches a demand response threshold |
7 | | level, in megawatts. |
8 | | (D) Utility-run demand-response programs, |
9 | | price-responsive demand programs, time-of-use, and |
10 | | hourly rate programs, beneficial electrification |
11 | | programs as described in Section 16-107.8 of the Public |
12 | | Utilities Act, any capacity value developed by the |
13 | | Illinois Commerce Commission as part of the |
14 | | distributed generation rebate described in Section |
15 | | 16-106.7 of the Public Utilities Act, or as otherwise |
16 | | provided for by the Commission. |
17 | | (E) Demand response and energy efficiency |
18 | | resources as defined by the Open Access Transmission |
19 | | Tariff and manuals of PJM Interconnection LLC. |
20 | | (5) To the extent practical, the Agency shall procure |
21 | | resources identified in subparagraphs (A) through (C) in |
22 | | paragraph (4) as part of the Carbon-Free Capacity |
23 | | Procurement described in paragraph (1) of subsection (k). |
24 | | (6) The Agency shall calculate the eligible capacity |
25 | | contribution of the items in paragraph (4) of this |
26 | | subsection (l) as part of any resource-specific carve-out |
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1 | | in the Open Access Transmission Tariff and manuals of PJM |
2 | | Interconnection LLC. |
3 | | (7) As part of its annual plan, the Agency shall |
4 | | solicit comment on new ways and methods for achieving |
5 | | cost-effective demand reductions to meet the goals of this |
6 | | subsection and, upon review, include new program proposals |
7 | | in its annual plan for review and approval by the |
8 | | Commission. |
9 | | (Source: P.A. 99-536, eff. 7-8-16; 99-906, eff. 6-1-17; |
10 | | 100-863, eff. 8-14-18; revised 10-18-18.) |
11 | | Section 90-15. The School Code is amended by adding Section |
12 | | 2-3.176 as follows: |
13 | | (105 ILCS 5/2-3.176 new) |
14 | | Sec. 2-3.176. Clean jobs curriculum. |
15 | | (a) The General Assembly recognizes that clean energy is a |
16 | | growing and important sector of the State's economy and that |
17 | | significant job opportunity exists in the sector. Consistent |
18 | | with Section 5-30 of the Clean Jobs Workforce Hubs Act, the |
19 | | Board shall participate in the development of the clean jobs |
20 | | curriculum convened by the Department of Commerce and Economic |
21 | | Opportunity. The Board shall identify and collaboratively with |
22 | | stakeholders identified by the Board develop curriculum based |
23 | | on anticipated clean energy job availability and growth. Clean |
24 | | energy jobs considered shall include, but are not limited to, |
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1 | | solar photovoltaic, solar thermal, wind energy, energy |
2 | | efficiency, site assessment, sales, and back office. |
3 | | (b) In the development of the clean jobs curriculum, the |
4 | | Board shall consider broad occupational training applicable to |
5 | | the general construction sector as well as sector-specific |
6 | | skills. |
7 | | (c) Consideration should be given to skills applicable to |
8 | | trainees for whom secondary and higher education has not been |
9 | | available. |
10 | | Section 90-20. The Public Utilities Act is amended by |
11 | | changing Sections 8-103B, 9-220.3, 16-107, 16-107.5, 16-107.6, |
12 | | 16-111.5, and 16-128B and by adding Sections 8-104.1, 16-107.7, |
13 | | 16-107.8, 16-108.9, 16-108.13, 16-108.17, and 16-115E as |
14 | | follows: |
15 | | (220 ILCS 5/8-103B) |
16 | | Sec. 8-103B. Energy efficiency and demand-response |
17 | | measures. |
18 | | (a) It is the policy of the State that electric utilities |
19 | | are required to use cost-effective energy efficiency and |
20 | | demand-response measures to reduce delivery load. Requiring |
21 | | investment in cost-effective energy efficiency and |
22 | | demand-response measures will reduce direct and indirect costs |
23 | | to consumers by decreasing environmental impacts and by |
24 | | avoiding or delaying the need for new generation, transmission, |
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1 | | and distribution infrastructure. It serves the public interest |
2 | | to allow electric utilities to recover costs for reasonably and |
3 | | prudently incurred expenditures for energy efficiency and |
4 | | demand-response measures. As used in this Section, |
5 | | "cost-effective" means that the measures satisfy the total |
6 | | resource cost test. The low-income measures described in |
7 | | subsection (c) of this Section shall not be required to meet |
8 | | the total resource cost test. For purposes of this Section, the |
9 | | terms "energy-efficiency", "demand-response", "electric |
10 | | utility", and "total resource cost test" have the meanings set |
11 | | forth in the Illinois Power Agency Act. |
12 | | (a-5) This Section applies to electric utilities serving |
13 | | more than 500,000 retail customers in the State for those |
14 | | multi-year plans commencing after December 31, 2017. |
15 | | (b) For purposes of this Section, electric utilities |
16 | | subject to this Section that serve more than 3,000,000 retail |
17 | | customers in the State shall be deemed to have achieved a |
18 | | cumulative persisting annual savings of 6.6% from energy |
19 | | efficiency measures and programs implemented during the period |
20 | | beginning January 1, 2012 and ending December 31, 2017, which |
21 | | percent is based on the deemed average weather normalized sales |
22 | | of electric power and energy during calendar years 2014, 2015, |
23 | | and 2016 of 88,000,000 MWhs. For the purposes of this |
24 | | subsection (b) and subsection (b-5), the 88,000,000 MWhs of |
25 | | deemed electric power and energy sales shall be reduced by the |
26 | | number of MWhs equal to the sum of the annual consumption of |
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1 | | customers that are exempt from subsections (a) through (j) of |
2 | | this Section under subsection (l) of this Section, as averaged |
3 | | across the calendar years 2014, 2015, and 2016. After 2017, the |
4 | | deemed value of cumulative persisting annual savings from |
5 | | energy efficiency measures and programs implemented during the |
6 | | period beginning January 1, 2012 and ending December 31, 2017, |
7 | | shall be reduced each year, as follows, and the applicable |
8 | | value shall be applied to and count toward the utility's |
9 | | achievement of the cumulative persisting annual savings goals |
10 | | set forth in subsection (b-5): |
11 | | (1) 5.8% deemed cumulative persisting annual savings |
12 | | for the year ending December 31, 2018; |
13 | | (2) 5.2% deemed cumulative persisting annual savings |
14 | | for the year ending December 31, 2019; |
15 | | (3) 4.5% deemed cumulative persisting annual savings |
16 | | for the year ending December 31, 2020; |
17 | | (4) 4.0% deemed cumulative persisting annual savings |
18 | | for the year ending December 31, 2021; |
19 | | (5) 3.5% deemed cumulative persisting annual savings |
20 | | for the year ending December 31, 2022; |
21 | | (6) 3.1% deemed cumulative persisting annual savings |
22 | | for the year ending December 31, 2023; |
23 | | (7) 2.8% deemed cumulative persisting annual savings |
24 | | for the year ending December 31, 2024; |
25 | | (8) 2.5% deemed cumulative persisting annual savings |
26 | | for the year ending December 31, 2025; |
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1 | | (9) 2.3% deemed cumulative persisting annual savings |
2 | | for the year ending December 31, 2026; |
3 | | (10) 2.1% deemed cumulative persisting annual savings |
4 | | for the year ending December 31, 2027; |
5 | | (11) 1.8% deemed cumulative persisting annual savings |
6 | | for the year ending December 31, 2028; |
7 | | (12) 1.7% deemed cumulative persisting annual savings |
8 | | for the year ending December 31, 2029; and |
9 | | (13) 1.5% deemed cumulative persisting annual savings |
10 | | for the year ending December 31, 2030 ; . |
11 | | (14) 1.3% deemed cumulative persisting annual savings |
12 | | for the year ending December 31, 2031; |
13 | | (15) 1.1% deemed cumulative persisting annual savings |
14 | | for the year ending December 31, 2032; |
15 | | (16) 0.9% deemed cumulative persisting annual savings |
16 | | for the year ending December 31, 2033; |
17 | | (17) 0.7% deemed cumulative persisting annual savings |
18 | | for the year ending December 31, 2034; |
19 | | (18) 0.5% deemed cumulative persisting annual savings |
20 | | for the year ending December 31, 2035; |
21 | | (19) 0.4% deemed cumulative persisting annual savings |
22 | | for the year ending December 31, 2036; |
23 | | (20) 0.3% deemed cumulative persisting annual savings |
24 | | for the year ending December 31, 2037; |
25 | | (21) 0.2% deemed cumulative persisting annual savings |
26 | | for the year ending December 31, 2038; |
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1 | | (22) 0.1% deemed cumulative persisting annual savings |
2 | | for the year ending December 31, 2039; and |
3 | | (23) 0.0% deemed cumulative persisting annual savings |
4 | | for the year ending December 31, 2040 and all subsequent |
5 | | years. |
6 | | For purposes of this Section, "cumulative persisting |
7 | | annual savings" means the total electric energy savings in a |
8 | | given year from measures installed in that year or in previous |
9 | | years, but no earlier than January 1, 2012, that are still |
10 | | operational and providing savings in that year because the |
11 | | measures have not yet reached the end of their useful lives. |
12 | | (b-5) Beginning in 2018, electric utilities subject to this |
13 | | Section that serve more than 3,000,000 retail customers in the |
14 | | State shall achieve the following cumulative persisting annual |
15 | | savings goals, as modified by subsection (f) of this Section |
16 | | and as compared to the deemed baseline of 88,000,000 MWhs of |
17 | | electric power and energy sales set forth in subsection (b), as |
18 | | reduced by the number of MWhs equal to the sum of the annual |
19 | | consumption of customers that are exempt from subsections (a) |
20 | | through (j) of this Section under subsection (l) of this |
21 | | Section as averaged across the calendar years 2014, 2015, and |
22 | | 2016, through the implementation of energy efficiency measures |
23 | | during the applicable year and in prior years, but no earlier |
24 | | than January 1, 2012: |
25 | | (1) 7.8% cumulative persisting annual savings for the |
26 | | year ending December 31, 2018; |
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1 | | (2) 9.1% cumulative persisting annual savings for the |
2 | | year ending December 31, 2019; |
3 | | (3) 10.4% cumulative persisting annual savings for the |
4 | | year ending December 31, 2020; |
5 | | (4) 11.8% cumulative persisting annual savings for the |
6 | | year ending December 31, 2021; |
7 | | (5) 13.1% cumulative persisting annual savings for the |
8 | | year ending December 31, 2022; |
9 | | (6) 14.4% cumulative persisting annual savings for the |
10 | | year ending December 31, 2023; |
11 | | (7) 15.7% cumulative persisting annual savings for the |
12 | | year ending December 31, 2024; |
13 | | (8) 17% cumulative persisting annual savings for the |
14 | | year ending December 31, 2025; |
15 | | (9) 17.9% cumulative persisting annual savings for the |
16 | | year ending December 31, 2026; |
17 | | (10) 18.8% cumulative persisting annual savings for |
18 | | the year ending December 31, 2027; |
19 | | (11) 19.7% cumulative persisting annual savings for |
20 | | the year ending December 31, 2028; |
21 | | (12) 20.6% cumulative persisting annual savings for |
22 | | the year ending December 31, 2029; and |
23 | | (13) 21.5% cumulative persisting annual savings for |
24 | | the year ending December 31, 2030. |
25 | | No later than December 31, 2020, the Illinois Commerce |
26 | | Commission shall establish additional cumulative persisting |
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1 | | annual savings goals for the years 2031 through 2035. The |
2 | | Commission shall also establish additional cumulative |
3 | | persisting annual savings goals every 5 years thereafter to |
4 | | ensure utilities always have goals that extend at least 11 |
5 | | years into the future. The cumulative persisting annual savings |
6 | | goals beyond the year 2030 shall increase by 0.9 percentage |
7 | | points per year, absent a Commission decision to initiate a |
8 | | proceeding to consider establishing goals that increase by more |
9 | | or less than that amount. Such a proceeding must be conducted |
10 | | in accordance with the procedures described in subsection (f) |
11 | | of this Section. If such a proceeding is initiated, the |
12 | | cumulative persisting annual savings goals established by the |
13 | | Commission through that proceeding shall reflect the |
14 | | Commission's best estimate of the maximum amount of additional |
15 | | savings that are forecast to be cost-effectively achievable |
16 | | unless such best estimates would result in goals that represent |
17 | | less than 0.5 percentage point annual increases in total |
18 | | cumulative persisting annual savings. The Commission may only |
19 | | establish goals that represent less than 0.5 percentage point |
20 | | annual increases in cumulative persisting annual savings if it |
21 | | can demonstrate, based on clear and convincing evidence, that |
22 | | 0.5 percentage point increases are not cost-effectively |
23 | | achievable. The Commission shall inform its decision based on |
24 | | an energy efficiency potential study which conforms to the |
25 | | requirements of subsection (f-5) of this Section. |
26 | | (b-10) For purposes of this Section, electric utilities |
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1 | | subject to this Section that serve less than 3,000,000 retail |
2 | | customers but more than 500,000 retail customers in the State |
3 | | shall be deemed to have achieved a cumulative persisting annual |
4 | | savings of 6.6% from energy efficiency measures and programs |
5 | | implemented during the period beginning January 1, 2012 and |
6 | | ending December 31, 2017, which is based on the deemed average |
7 | | weather normalized sales of electric power and energy during |
8 | | calendar years 2014, 2015, and 2016 of 36,900,000 MWhs. For the |
9 | | purposes of this subsection (b-10) and subsection (b-15), the |
10 | | 36,900,000 MWhs of deemed electric power and energy sales shall |
11 | | be reduced by the number of MWhs equal to the sum of the annual |
12 | | consumption of customers that are exempt from subsections (a) |
13 | | through (j) of this Section under subsection (l) of this |
14 | | Section, as averaged across the calendar years 2014, 2015, and |
15 | | 2016. After 2017, the deemed value of cumulative persisting |
16 | | annual savings from energy efficiency measures and programs |
17 | | implemented during the period beginning January 1, 2012 and |
18 | | ending December 31, 2017, shall be reduced each year, as |
19 | | follows, and the applicable value shall be applied to and count |
20 | | toward the utility's achievement of the cumulative persisting |
21 | | annual savings goals set forth in subsection (b-15): |
22 | | (1) 5.8% deemed cumulative persisting annual savings |
23 | | for the year ending December 31, 2018; |
24 | | (2) 5.2% deemed cumulative persisting annual savings |
25 | | for the year ending December 31, 2019; |
26 | | (3) 4.5% deemed cumulative persisting annual savings |
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1 | | for the year ending December 31, 2020; |
2 | | (4) 4.0% deemed cumulative persisting annual savings |
3 | | for the year ending December 31, 2021; |
4 | | (5) 3.5% deemed cumulative persisting annual savings |
5 | | for the year ending December 31, 2022; |
6 | | (6) 3.1% deemed cumulative persisting annual savings |
7 | | for the year ending December 31, 2023; |
8 | | (7) 2.8% deemed cumulative persisting annual savings |
9 | | for the year ending December 31, 2024; |
10 | | (8) 2.5% deemed cumulative persisting annual savings |
11 | | for the year ending December 31, 2025; |
12 | | (9) 2.3% deemed cumulative persisting annual savings |
13 | | for the year ending December 31, 2026; |
14 | | (10) 2.1% deemed cumulative persisting annual savings |
15 | | for the year ending December 31, 2027; |
16 | | (11) 1.8% deemed cumulative persisting annual savings |
17 | | for the year ending December 31, 2028; |
18 | | (12) 1.7% deemed cumulative persisting annual savings |
19 | | for the year ending December 31, 2029; and |
20 | | (13) 1.5% deemed cumulative persisting annual savings |
21 | | for the year ending December 31, 2030 ; . |
22 | | (14) 1.3% deemed cumulative persisting annual savings |
23 | | for the year ending December 31, 2031; |
24 | | (15) 1.1% deemed cumulative persisting annual savings |
25 | | for the year ending December 31, 2032; |
26 | | (16) 0.9% deemed cumulative persisting annual savings |
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1 | | for the year ending December 31, 2033; |
2 | | (17) 0.7% deemed cumulative persisting annual savings |
3 | | for the year ending December 31, 2034; |
4 | | (18) 0.5% deemed cumulative persisting annual savings |
5 | | for the year ending December 31, 2035; |
6 | | (19) 0.4% deemed cumulative persisting annual savings |
7 | | for the year ending December 31, 2036; |
8 | | (20) 0.3% deemed cumulative persisting annual savings |
9 | | for the year ending December 31, 2037; |
10 | | (21) 0.2% deemed cumulative persisting annual savings |
11 | | for the year ending December 31, 2038; |
12 | | (22) 0.1% deemed cumulative persisting annual savings |
13 | | for the year ending December 31, 2039; and |
14 | | (23) 0.0% deemed cumulative persisting annual savings |
15 | | for the year ending December 31, 2040 and all subsequent |
16 | | years. |
17 | | (b-15) Beginning in 2018, electric utilities subject to |
18 | | this Section that serve less than 3,000,000 retail customers |
19 | | but more than 500,000 retail customers in the State shall |
20 | | achieve the following cumulative persisting annual savings |
21 | | goals , as modified by subsection (b-20) and subsection (f) of |
22 | | this Section and as compared to the deemed baseline as reduced |
23 | | by the number of MWhs equal to the sum of the annual |
24 | | consumption of customers that are exempt from subsections (a) |
25 | | through (j) of this Section under subsection (l) of this |
26 | | Section as averaged across the calendar years 2014, 2015, and |
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1 | | 2016, through the implementation of energy efficiency measures |
2 | | during the applicable year and in prior years, but no earlier |
3 | | than January 1, 2012: |
4 | | (1) 7.4% cumulative persisting annual savings for the |
5 | | year ending December 31, 2018; |
6 | | (2) 8.2% cumulative persisting annual savings for the |
7 | | year ending December 31, 2019; |
8 | | (3) 9.0% cumulative persisting annual savings for the |
9 | | year ending December 31, 2020; |
10 | | (4) 9.8% cumulative persisting annual savings for the |
11 | | year ending December 31, 2021; |
12 | | (5) 10.6% cumulative persisting annual savings for the |
13 | | year ending December 31, 2022; |
14 | | (6) 11.4% cumulative persisting annual savings for the |
15 | | year ending December 31, 2023; |
16 | | (7) 12.2% cumulative persisting annual savings for the |
17 | | year ending December 31, 2024; |
18 | | (8) 13% cumulative persisting annual savings for the |
19 | | year ending December 31, 2025; |
20 | | (9) 13.6% cumulative persisting annual savings for the |
21 | | year ending December 31, 2026; |
22 | | (10) 14.2% cumulative persisting annual savings for |
23 | | the year ending December 31, 2027; |
24 | | (11) 14.8% cumulative persisting annual savings for |
25 | | the year ending December 31, 2028; |
26 | | (12) 15.4% cumulative persisting annual savings for |
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1 | | the year ending December 31, 2029; and |
2 | | (13) 16% cumulative persisting annual savings for the |
3 | | year ending December 31, 2030. |
4 | | No later than December 31, 2020, the Illinois Commerce |
5 | | Commission shall establish additional cumulative persisting |
6 | | annual savings goals for the years 2031 through 2035. The |
7 | | Commission shall also establish additional cumulative |
8 | | persisting annual savings goals every 5 years thereafter to |
9 | | ensure utilities always have goals that extend at least 11 |
10 | | years into the future. The cumulative persisting annual savings |
11 | | goals beyond the year 2030 shall increase by 0.6 percentage |
12 | | points per year, absent a Commission decision to initiate a |
13 | | proceeding to consider establishing goals that increase by more |
14 | | or less than that amount. Such a proceeding must be conducted |
15 | | in accordance with the procedures described in subsection (f)of |
16 | | this Section. If such a proceeding is initiated, the cumulative |
17 | | persisting annual savings goals established by the Commission |
18 | | through that proceeding shall reflect the Commission's best |
19 | | estimate of the maximum amount of additional savings that are |
20 | | forecast to be cost-effectively achievable unless such best |
21 | | estimates would result in goals that represent less than 0.4 |
22 | | percentage point annual increases in total cumulative |
23 | | persisting annual savings. The Commission may only establish |
24 | | goals that represent less than 0.4 percentage point annual |
25 | | increases in cumulative persisting annual savings if it can |
26 | | demonstrate, based on clear and convincing evidence, that 0.4 |
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1 | | percentage point increases are not cost-effectively |
2 | | achievable. The Commission shall inform its decision based on |
3 | | an energy efficiency potential study which conforms to the |
4 | | requirements of subsection (f-5) of this Section. |
5 | | The difference between the cumulative persisting annual |
6 | | savings goal for the applicable calendar year and the |
7 | | cumulative persisting annual savings goal for the immediately |
8 | | preceding calendar year is 0.8% for the period of January 1, |
9 | | 2018 through December 31, 2025 and 0.6% for the period of |
10 | | January 1, 2026 through December 31, 2030. |
11 | | (b-20) Each electric utility subject to this Section may |
12 | | include cost-effective voltage optimization measures in its |
13 | | plans submitted under subsections (f) and (g) of this Section, |
14 | | and the costs incurred by a utility to implement the measures |
15 | | under a Commission-approved plan shall be recovered under the |
16 | | provisions of Article IX or Section 16-108.5 of this Act. For |
17 | | purposes of this Section, the measure life of voltage |
18 | | optimization measures shall be 15 years. The measure life |
19 | | period is independent of the depreciation rate of the voltage |
20 | | optimization assets deployed. Utilities may claim savings from |
21 | | voltage optimization on circuits for more than 15 years if they |
22 | | can demonstrate that they have made additional investments |
23 | | necessary to enable voltage optimization savings to continue |
24 | | beyond 15 years. Such demonstrations must be subject to the |
25 | | review of independent evaluation. |
26 | | Within 270 days after June 1, 2017 ( the effective date of |
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1 | | Public Act 99-906) this amendatory Act of the 99th General |
2 | | Assembly , an electric utility that serves less than 3,000,000 |
3 | | retail customers but more than 500,000 retail customers in the |
4 | | State shall file a plan with the Commission that identifies the |
5 | | cost-effective voltage optimization investment the electric |
6 | | utility plans to undertake through December 31, 2024. The |
7 | | Commission, after notice and hearing, shall approve or approve |
8 | | with modification the plan within 120 days after the plan's |
9 | | filing and, in the order approving or approving with |
10 | | modification the plan, the Commission shall adjust the |
11 | | applicable cumulative persisting annual savings goals set |
12 | | forth in subsection (b-15) to reflect any amount of |
13 | | cost-effective energy savings approved by the Commission that |
14 | | is greater than or less than the following cumulative |
15 | | persisting annual savings values attributable to voltage |
16 | | optimization for the applicable year: |
17 | | (1) 0.0% of cumulative persisting annual savings for |
18 | | the year ending December 31, 2018; |
19 | | (2) 0.17% of cumulative persisting annual savings for |
20 | | the year ending December 31, 2019; |
21 | | (3) 0.17% of cumulative persisting annual savings for |
22 | | the year ending December 31, 2020; |
23 | | (4) 0.33% of cumulative persisting annual savings for |
24 | | the year ending December 31, 2021; |
25 | | (5) 0.5% of cumulative persisting annual savings for |
26 | | the year ending December 31, 2022; |
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1 | | (6) 0.67% of cumulative persisting annual savings for |
2 | | the year ending December 31, 2023; |
3 | | (7) 0.83% of cumulative persisting annual savings for |
4 | | the year ending December 31, 2024; and |
5 | | (8) 1.0% of cumulative persisting annual savings for |
6 | | the year ending December 31, 2025 and all subsequent years . |
7 | | (b-25) In the event an electric utility jointly offers an |
8 | | energy efficiency measure or program with a gas utility under |
9 | | plans approved under this Section and Section 8-104 of this |
10 | | Act, the electric utility may continue offering the program, |
11 | | including the gas energy efficiency measures, in the event the |
12 | | gas utility discontinues funding the program. In that event, |
13 | | the energy savings value associated with such other fuels shall |
14 | | be converted to electric energy savings on an equivalent Btu |
15 | | basis for the premises. However, the electric utility shall |
16 | | prioritize programs for low-income residential customers to |
17 | | the extent practicable. An electric utility may recover the |
18 | | costs of offering the gas energy efficiency measures under this |
19 | | subsection (b-25). |
20 | | For those energy efficiency measures or programs that save |
21 | | both electricity and other fuels but are not jointly offered |
22 | | with a gas utility under plans approved under this Section and |
23 | | Section 8-104 or not offered with an affiliated gas utility |
24 | | under paragraph (6) of subsection (f) of Section 8-104 of this |
25 | | Act, the electric utility may count savings of fuels other than |
26 | | electricity toward the achievement of its annual savings goal, |
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1 | | and the energy savings value associated with such other fuels |
2 | | shall be converted to electric energy savings on an equivalent |
3 | | Btu basis at the premises. |
4 | | In no event shall more than 10% of each year's applicable |
5 | | annual total savings requirement incremental goal as defined in |
6 | | paragraph (7) of subsection (g) of this Section be met through |
7 | | savings of fuels other than electricity. |
8 | | (c) Electric utilities shall be responsible for overseeing |
9 | | the design, development, and filing of energy efficiency plans |
10 | | with the Commission and may, as part of that implementation, |
11 | | outsource various aspects of program development and |
12 | | implementation. A minimum of 10%, for electric utilities that |
13 | | serve more than 3,000,000 retail customers in the State, and a |
14 | | minimum of 7%, for electric utilities that serve less than |
15 | | 3,000,000 retail customers but more than 500,000 retail |
16 | | customers in the State, of the utility's entire portfolio |
17 | | funding level for a given year shall be used to procure |
18 | | cost-effective energy efficiency measures from units of local |
19 | | government, municipal corporations, school districts, public |
20 | | housing, and community college districts , and buildings owned |
21 | | by nonprofit organizations, , provided that a minimum |
22 | | percentage of available funds shall be used to procure energy |
23 | | efficiency from public housing, which percentage shall be equal |
24 | | to public housing's share of public building energy |
25 | | consumption. |
26 | | The utilities shall also implement energy efficiency |
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1 | | measures targeted at low-income households, which, for |
2 | | purposes of this Section, shall be defined as households at or |
3 | | below 80% of area median income, and expenditures to implement |
4 | | the measures shall be no less than $35,000,000 $25,000,000 per |
5 | | year for electric utilities that serve more than 3,000,000 |
6 | | retail customers in the State and no less than $11,000,000 |
7 | | $8,350,000 per year for electric utilities that serve less than |
8 | | 3,000,000 retail customers but more than 500,000 retail |
9 | | customers in the State. Spending on efficiency programs |
10 | | targeted at low-income households shall be approximately |
11 | | proportional to the magnitude of cost-effective energy |
12 | | efficiency opportunities in low-income single-family and |
13 | | multi-family buildings. |
14 | | The utilities shall work to bundle low-income energy |
15 | | efficiency offerings with other programs that serve low-income |
16 | | households to maximize the benefits going to these households. |
17 | | The utilities shall market and implement low-income energy |
18 | | efficiency programs in coordination with low-income assistance |
19 | | programs, Solar for All, and weatherization whenever |
20 | | practicable. The program implementer shall walk the customer |
21 | | through the enrollment process for any programs for which the |
22 | | customer is eligible. The utilities shall also pilot targeting |
23 | | customers with high arrearages, high energy intensity (ratio of |
24 | | energy usage divided by home or unit square footage), or energy |
25 | | assistance programs with energy efficiency offerings, and then |
26 | | track reduction in arrearages as a result of the targeting. |
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1 | | This targeting and bundling of low-income energy programs shall |
2 | | be offered to both low-income single-family and multi-family |
3 | | customers (owners and residents). |
4 | | The utilities shall also implement a health and safety fund |
5 | | of a minimum of 0.5%, for electric utilities that serve more |
6 | | than 3,000,000 retail customers in the State, and a minimum of |
7 | | 0.5%, for electric utilities that serve less than 3,000,000 |
8 | | retail customers but more than 500,000 retail customers in the |
9 | | State, of the utility's entire portfolio funding level for a |
10 | | given year, that shall be used for the purpose of making grants |
11 | | for technical assistance, construction, reconstruction, |
12 | | improvement, or repair of buildings to facilitate their |
13 | | participation in the energy efficiency programs targeted at |
14 | | low-income single-family and multi-family households. These |
15 | | funds may also be used for the purpose of making grants for |
16 | | technical assistance, construction, reconstruction, |
17 | | improvement, or repair of the following buildings to facilitate |
18 | | their participation in the energy efficiency programs created |
19 | | by this Section: (1) buildings that are owned or operated by |
20 | | registered 501(c)(3) public charities; and (2) day care |
21 | | centers, day care homes, or group day care homes, as defined |
22 | | under 89 Ill. Adm. Code Part 406, 407, or 408, respectively. |
23 | | Each electric utility shall assess opportunities to |
24 | | implement cost-effective energy efficiency measures and |
25 | | programs through a public housing authority or authorities |
26 | | located in its service territory. If such opportunities are |
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1 | | identified, the utility shall propose such measures and |
2 | | programs to address the opportunities. Expenditures to address |
3 | | such opportunities shall be credited toward the minimum |
4 | | procurement and expenditure requirements set forth in this |
5 | | subsection (c). |
6 | | Implementation of energy efficiency measures and programs |
7 | | targeted at low-income households should be contracted, when it |
8 | | is practicable, to independent third parties that have |
9 | | demonstrated capabilities to serve such households, with a |
10 | | preference for not-for-profit entities and government agencies |
11 | | that have existing relationships with or experience serving |
12 | | low-income communities in the State. |
13 | | Each electric utility shall develop and implement |
14 | | reporting procedures that address and assist in determining the |
15 | | amount of energy savings that can be applied to the low-income |
16 | | procurement and expenditure requirements set forth in this |
17 | | subsection (c). |
18 | | The electric utilities participate in shall also convene a |
19 | | low-income energy efficiency advisory committee to allow a |
20 | | variety of stakeholders, especially those living or working in |
21 | | low-communities, to assist in the design and evaluation of the |
22 | | low-income energy efficiency programs. The committee shall be |
23 | | comprised of the electric utilities subject to the requirements |
24 | | of this Section, the gas utilities subject to the requirements |
25 | | of Section 8-104.1 8-104 of this Act, the utilities' low-income |
26 | | energy efficiency implementation contractors, nonprofit |
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1 | | organizations, community action agencies, advocacy groups, |
2 | | State and local governmental agencies, and representatives of |
3 | | community-based organizations. The committee shall be convened |
4 | | by an independent third-party facilitator and a |
5 | | community-based organization in a low-income community. There |
6 | | shall be a leadership committee comprised of a variety of |
7 | | stakeholders, with at least one community-based organization |
8 | | involved. Meetings shall include concrete opportunities for |
9 | | groups to provide meaningful input into plan design, mid-cycle |
10 | | changes, and evaluation throughout the year to help reduce |
11 | | litigation in future plan filings. All meetings must be |
12 | | accessible, with rotating locations, call-in options, and |
13 | | materials and agendas circulated well in advance. There shall |
14 | | also be opportunities for input outside of meetings from those |
15 | | with limited capacity and ability to attend, via one-on-one |
16 | | meetings, surveys, and calls. Meetings shall also include |
17 | | opportunities to bundle and coordinate low-income energy |
18 | | efficiency with Solar for All and energy assistance programs. |
19 | | Meetings shall include educational opportunities for |
20 | | stakeholders to learn more about these additional offerings, |
21 | | and the committee shall assist in the figuring out the best |
22 | | methods for coordinated delivery and implementation of |
23 | | offerings when serving low-income communities. |
24 | | (d) Notwithstanding any other provision of law to the |
25 | | contrary, a utility providing approved energy efficiency |
26 | | measures and, if applicable, demand-response measures in the |
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1 | | State shall be permitted to recover all reasonable and |
2 | | prudently incurred costs of those measures from all retail |
3 | | customers, except as provided in subsection (l) of this |
4 | | Section, as follows, provided that nothing in this subsection |
5 | | (d) permits the double recovery of such costs from customers: |
6 | | (1) The utility may recover its costs through an |
7 | | automatic adjustment clause tariff filed with and approved |
8 | | by the Commission. The tariff shall be established outside |
9 | | the context of a general rate case. Each year the |
10 | | Commission shall initiate a review to reconcile any amounts |
11 | | collected with the actual costs and to determine the |
12 | | required adjustment to the annual tariff factor to match |
13 | | annual expenditures. To enable the financing of the |
14 | | incremental capital expenditures, including regulatory |
15 | | assets, for electric utilities that serve less than |
16 | | 3,000,000 retail customers but more than 500,000 retail |
17 | | customers in the State, the utility's actual year-end |
18 | | capital structure that includes a common equity ratio, |
19 | | excluding goodwill, of up to and including 50% of the total |
20 | | capital structure shall be deemed reasonable and used to |
21 | | set rates. |
22 | | (2) A utility may recover its costs through an energy |
23 | | efficiency formula rate approved by the Commission under a |
24 | | filing under subsections (f) and (g) of this Section, which |
25 | | shall specify the cost components that form the basis of |
26 | | the rate charged to customers with sufficient specificity |
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1 | | to operate in a standardized manner and be updated annually |
2 | | with transparent information that reflects the utility's |
3 | | actual costs to be recovered during the applicable rate |
4 | | year, which is the period beginning with the first billing |
5 | | day of January and extending through the last billing day |
6 | | of the following December. The energy efficiency formula |
7 | | rate shall be implemented through a tariff filed with the |
8 | | Commission under subsections (f) and (g) of this Section |
9 | | that is consistent with the provisions of this paragraph |
10 | | (2) and that shall be applicable to all delivery services |
11 | | customers. The Commission shall conduct an investigation |
12 | | of the tariff in a manner consistent with the provisions of |
13 | | this paragraph (2), subsections (f) and (g) of this |
14 | | Section, and the provisions of Article IX of this Act to |
15 | | the extent they do not conflict with this paragraph (2). |
16 | | The energy efficiency formula rate approved by the |
17 | | Commission shall remain in effect at the discretion of the |
18 | | utility and shall do the following: |
19 | | (A) Provide for the recovery of the utility's |
20 | | actual costs incurred under this Section that are |
21 | | prudently incurred and reasonable in amount consistent |
22 | | with Commission practice and law. The sole fact that a |
23 | | cost differs from that incurred in a prior calendar |
24 | | year or that an investment is different from that made |
25 | | in a prior calendar year shall not imply the imprudence |
26 | | or unreasonableness of that cost or investment. |
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1 | | (B) Reflect the utility's actual year-end capital |
2 | | structure for the applicable calendar year, excluding |
3 | | goodwill, subject to a determination of prudence and |
4 | | reasonableness consistent with Commission practice and |
5 | | law. To enable the financing of the incremental capital |
6 | | expenditures, including regulatory assets, for |
7 | | electric utilities that serve less than 3,000,000 |
8 | | retail customers but more than 500,000 retail |
9 | | customers in the State, a participating electric |
10 | | utility's actual year-end capital structure that |
11 | | includes a common equity ratio, excluding goodwill, of |
12 | | up to and including 50% of the total capital structure |
13 | | shall be deemed reasonable and used to set rates. |
14 | | (C) Include a cost of equity, which shall be |
15 | | calculated as the sum of the following: |
16 | | (i) the average for the applicable calendar |
17 | | year of the monthly average yields of 30-year U.S. |
18 | | Treasury bonds published by the Board of Governors |
19 | | of the Federal Reserve System in its weekly H.15 |
20 | | Statistical Release or successor publication; and |
21 | | (ii) 580 basis points. |
22 | | At such time as the Board of Governors of the |
23 | | Federal Reserve System ceases to include the monthly |
24 | | average yields of 30-year U.S. Treasury bonds in its |
25 | | weekly H.15 Statistical Release or successor |
26 | | publication, the monthly average yields of the U.S. |
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1 | | Treasury bonds then having the longest duration |
2 | | published by the Board of Governors in its weekly H.15 |
3 | | Statistical Release or successor publication shall |
4 | | instead be used for purposes of this paragraph (2). |
5 | | (D) Permit and set forth protocols, subject to a |
6 | | determination of prudence and reasonableness |
7 | | consistent with Commission practice and law, for the |
8 | | following: |
9 | | (i) recovery of incentive compensation expense |
10 | | that is based on the achievement of operational |
11 | | metrics, including metrics related to budget |
12 | | controls, outage duration and frequency, safety, |
13 | | customer service, efficiency and productivity, and |
14 | | environmental compliance; however, this protocol |
15 | | shall not apply if such expense related to costs |
16 | | incurred under this Section is recovered under |
17 | | Article IX or Section 16-108.5 of this Act; |
18 | | incentive compensation expense that is based on |
19 | | net income or an affiliate's earnings per share |
20 | | shall not be recoverable under the
energy |
21 | | efficiency formula rate; |
22 | | (ii) recovery of pension and other |
23 | | post-employment benefits expense, provided that |
24 | | such costs are supported by an actuarial study; |
25 | | however, this protocol shall not apply if such |
26 | | expense related to costs incurred under this |
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1 | | Section is recovered under Article IX or Section |
2 | | 16-108.5 of this Act; |
3 | | (iii) recovery of existing regulatory assets |
4 | | over the periods previously authorized by the |
5 | | Commission; |
6 | | (iv) as described in subsection (e), |
7 | | amortization of costs incurred under this Section; |
8 | | and |
9 | | (v) projected, weather normalized billing |
10 | | determinants for the applicable rate year. |
11 | | (E) Provide for an annual reconciliation, as |
12 | | described in paragraph (3) of this subsection (d), less |
13 | | any deferred taxes related to the reconciliation, with |
14 | | interest at an annual rate of return equal to the |
15 | | utility's weighted average cost of capital, including |
16 | | a revenue conversion factor calculated to recover or |
17 | | refund all additional income taxes that may be payable |
18 | | or receivable as a result of that return, of the energy |
19 | | efficiency revenue requirement reflected in rates for |
20 | | each calendar year, beginning with the calendar year in |
21 | | which the utility files its energy efficiency formula |
22 | | rate tariff under this paragraph (2), with what the |
23 | | revenue requirement would have been had the actual cost |
24 | | information for the applicable calendar year been |
25 | | available at the filing date. |
26 | | The utility shall file, together with its tariff, the |
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1 | | projected costs to be incurred by the utility during the |
2 | | rate year under the utility's multi-year plan approved |
3 | | under subsections (f) and (g) of this Section, including, |
4 | | but not limited to, the projected capital investment costs |
5 | | and projected regulatory asset balances with |
6 | | correspondingly updated depreciation and amortization |
7 | | reserves and expense, that shall populate the energy |
8 | | efficiency formula rate and set the initial rates under the |
9 | | formula. |
10 | | The Commission shall review the proposed tariff in |
11 | | conjunction with its review of a proposed multi-year plan, |
12 | | as specified in paragraph (5) of subsection (g) of this |
13 | | Section. The review shall be based on the same evidentiary |
14 | | standards, including, but not limited to, those concerning |
15 | | the prudence and reasonableness of the costs incurred by |
16 | | the utility, the Commission applies in a hearing to review |
17 | | a filing for a general increase in rates under Article IX |
18 | | of this Act. The initial rates shall take effect beginning |
19 | | with the January monthly billing period following the |
20 | | Commission's approval. |
21 | | The tariff's rate design and cost allocation across |
22 | | customer classes shall be consistent with the utility's |
23 | | automatic adjustment clause tariff in effect on June 1, |
24 | | 2017 ( the effective date of Public Act 99-906) this |
25 | | amendatory Act of the 99th General Assembly ; however, the |
26 | | Commission may revise the tariff's rate design and cost |
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1 | | allocation in subsequent proceedings under paragraph (3) |
2 | | of this subsection (d). |
3 | | If the energy efficiency formula rate is terminated, |
4 | | the then current rates shall remain in effect until such |
5 | | time as the energy efficiency costs are incorporated into |
6 | | new rates that are set under this subsection (d) or Article |
7 | | IX of this Act, subject to retroactive rate adjustment, |
8 | | with interest, to reconcile rates charged with actual |
9 | | costs. |
10 | | (3) The provisions of this paragraph (3) shall only |
11 | | apply to an electric utility that has elected to file an |
12 | | energy efficiency formula rate under paragraph (2) of this |
13 | | subsection (d). Subsequent to the Commission's issuance of |
14 | | an order approving the utility's energy efficiency formula |
15 | | rate structure and protocols, and initial rates under |
16 | | paragraph (2) of this subsection (d), the utility shall |
17 | | file, on or before June 1 of each year, with the Chief |
18 | | Clerk of the Commission its updated cost inputs to the |
19 | | energy efficiency formula rate for the applicable rate year |
20 | | and the corresponding new charges, as well as the |
21 | | information described in paragraph (9) of subsection (g) of |
22 | | this Section. Each such filing shall conform to the |
23 | | following requirements and include the following |
24 | | information: |
25 | | (A) The inputs to the energy efficiency formula |
26 | | rate for the applicable rate year shall be based on the |
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1 | | projected costs to be incurred by the utility during |
2 | | the rate year under the utility's multi-year plan |
3 | | approved under subsections (f) and (g) of this Section, |
4 | | including, but not limited to, projected capital |
5 | | investment costs and projected regulatory asset |
6 | | balances with correspondingly updated depreciation and |
7 | | amortization reserves and expense. The filing shall |
8 | | also include a reconciliation of the energy efficiency |
9 | | revenue requirement that was in effect for the prior |
10 | | rate year (as set by the cost inputs for the prior rate |
11 | | year) with the actual revenue requirement for the prior |
12 | | rate year (determined using a year-end rate base) that |
13 | | uses amounts reflected in the applicable FERC Form 1 |
14 | | that reports the actual costs for the prior rate year. |
15 | | Any over-collection or under-collection indicated by |
16 | | such reconciliation shall be reflected as a credit |
17 | | against, or recovered as an additional charge to, |
18 | | respectively, with interest calculated at a rate equal |
19 | | to the utility's weighted average cost of capital |
20 | | approved by the Commission for the prior rate year, the |
21 | | charges for the applicable rate year. Such |
22 | | over-collection or under-collection shall be adjusted |
23 | | to remove any deferred taxes related to the |
24 | | reconciliation, for purposes of calculating interest |
25 | | at an annual rate of return equal to the utility's |
26 | | weighted average cost of capital approved by the |
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1 | | Commission for the prior rate year, including a revenue |
2 | | conversion factor calculated to recover or refund all |
3 | | additional income taxes that may be payable or |
4 | | receivable as a result of that return. Each |
5 | | reconciliation shall be certified by the participating |
6 | | utility in the same manner that FERC Form 1 is |
7 | | certified. The filing shall also include the charge or |
8 | | credit, if any, resulting from the calculation |
9 | | required by subparagraph (E) of paragraph (2) of this |
10 | | subsection (d). |
11 | | Notwithstanding any other provision of law to the |
12 | | contrary, the intent of the reconciliation is to |
13 | | ultimately reconcile both the revenue requirement |
14 | | reflected in rates for each calendar year, beginning |
15 | | with the calendar year in which the utility files its |
16 | | energy efficiency formula rate tariff under paragraph |
17 | | (2) of this subsection (d), with what the revenue |
18 | | requirement determined using a year-end rate base for |
19 | | the applicable calendar year would have been had the |
20 | | actual cost information for the applicable calendar |
21 | | year been available at the filing date. |
22 | | For purposes of this Section, "FERC Form 1" means |
23 | | the Annual Report of Major Electric Utilities, |
24 | | Licensees and Others that electric utilities are |
25 | | required to file with the Federal Energy Regulatory |
26 | | Commission under the Federal Power Act, Sections 3, |
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1 | | 4(a), 304 and 209, modified as necessary to be |
2 | | consistent with 83 Ill. Admin. Code Part 415 as of May |
3 | | 1, 2011. Nothing in this Section is intended to allow |
4 | | costs that are not otherwise recoverable to be |
5 | | recoverable by virtue of inclusion in FERC Form 1. |
6 | | (B) The new charges shall take effect beginning on |
7 | | the first billing day of the following January billing |
8 | | period and remain in effect through the last billing |
9 | | day of the next December billing period regardless of |
10 | | whether the Commission enters upon a hearing under this |
11 | | paragraph (3). |
12 | | (C) The filing shall include relevant and |
13 | | necessary data and documentation for the applicable |
14 | | rate year. Normalization adjustments shall not be |
15 | | required. |
16 | | Within 45 days after the utility files its annual |
17 | | update of cost inputs to the energy efficiency formula |
18 | | rate, the Commission shall with reasonable notice, |
19 | | initiate a proceeding concerning whether the projected |
20 | | costs to be incurred by the utility and recovered during |
21 | | the applicable rate year, and that are reflected in the |
22 | | inputs to the energy efficiency formula rate, are |
23 | | consistent with the utility's approved multi-year plan |
24 | | under subsections (f) and (g) of this Section and whether |
25 | | the costs incurred by the utility during the prior rate |
26 | | year were prudent and reasonable. The Commission shall also |
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1 | | have the authority to investigate the information and data |
2 | | described in paragraph (9) of subsection (g) of this |
3 | | Section, including the proposed adjustment to the |
4 | | utility's return on equity component of its weighted |
5 | | average cost of capital. During the course of the |
6 | | proceeding, each objection shall be stated with |
7 | | particularity and evidence provided in support thereof, |
8 | | after which the utility shall have the opportunity to rebut |
9 | | the evidence. Discovery shall be allowed consistent with |
10 | | the Commission's Rules of Practice, which Rules of Practice |
11 | | shall be enforced by the Commission or the assigned |
12 | | administrative law judge. The Commission shall apply the |
13 | | same evidentiary standards, including, but not limited to, |
14 | | those concerning the prudence and reasonableness of the |
15 | | costs incurred by the utility, during the proceeding as it |
16 | | would apply in a proceeding to review a filing for a |
17 | | general increase in rates under Article IX of this Act. The |
18 | | Commission shall not, however, have the authority in a |
19 | | proceeding under this paragraph (3) to consider or order |
20 | | any changes to the structure or protocols of the energy |
21 | | efficiency formula rate approved under paragraph (2) of |
22 | | this subsection (d). In a proceeding under this paragraph |
23 | | (3), the Commission shall enter its order no later than the |
24 | | earlier of 195 days after the utility's filing of its |
25 | | annual update of cost inputs to the energy efficiency |
26 | | formula rate or December 15. The utility's proposed return |
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1 | | on equity calculation, as described in paragraphs (7) |
2 | | through (9) of subsection (g) of this Section, shall be |
3 | | deemed the final, approved calculation on December 15 of |
4 | | the year in which it is filed unless the Commission enters |
5 | | an order on or before December 15, after notice and |
6 | | hearing, that modifies such calculation consistent with |
7 | | this Section. The Commission's determinations of the |
8 | | prudence and reasonableness of the costs incurred, and |
9 | | determination of such return on equity calculation, for the |
10 | | applicable calendar year shall be final upon entry of the |
11 | | Commission's order and shall not be subject to reopening, |
12 | | reexamination, or collateral attack in any other |
13 | | Commission proceeding, case, docket, order, rule, or |
14 | | regulation; however, nothing in this paragraph (3) shall |
15 | | prohibit a party from petitioning the Commission to rehear |
16 | | or appeal to the courts the order under the provisions of |
17 | | this Act. |
18 | | (e)
Beginning on June 1, 2017 ( the effective date of Public |
19 | | Act 99-906) this amendatory Act of the 99th General Assembly , a |
20 | | utility subject to the requirements of this Section may elect |
21 | | to defer, as a regulatory asset, up to the full amount of its |
22 | | expenditures incurred under this Section for each annual |
23 | | period, including, but not limited to, any expenditures |
24 | | incurred above the funding level set by subsection (f) of this |
25 | | Section for a given year. The total expenditures deferred as a |
26 | | regulatory asset in a given year shall be amortized and |
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1 | | recovered over a period that is equal to the weighted average |
2 | | of the energy efficiency measure lives implemented for that |
3 | | year that are reflected in the regulatory asset. The |
4 | | unamortized balance shall be recognized as of December 31 for a |
5 | | given year. The utility shall also earn a return on the total |
6 | | of the unamortized balances of all of the energy efficiency |
7 | | regulatory assets, less any deferred taxes related to those |
8 | | unamortized balances, at an annual rate equal to the utility's |
9 | | weighted average cost of capital that includes, based on a |
10 | | year-end capital structure, the utility's actual cost of debt |
11 | | for the applicable calendar year and a cost of equity, which |
12 | | shall be calculated as the sum of the (i) the average for the |
13 | | applicable calendar year of the monthly average yields of |
14 | | 30-year U.S. Treasury bonds published by the Board of Governors |
15 | | of the Federal Reserve System in its weekly H.15 Statistical |
16 | | Release or successor publication; and (ii) 580 basis points, |
17 | | including a revenue conversion factor calculated to recover or |
18 | | refund all additional income taxes that may be payable or |
19 | | receivable as a result of that return. Capital investment costs |
20 | | shall be depreciated and recovered over their useful lives |
21 | | consistent with generally accepted accounting principles. The |
22 | | weighted average cost of capital shall be applied to the |
23 | | capital investment cost balance, less any accumulated |
24 | | depreciation and accumulated deferred income taxes, as of |
25 | | December 31 for a given year. |
26 | | When an electric utility creates a regulatory asset under |
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1 | | the provisions of this Section, the costs are recovered over a |
2 | | period during which customers also receive a benefit which is |
3 | | in the public interest. Accordingly, it is the intent of the |
4 | | General Assembly that an electric utility that elects to create |
5 | | a regulatory asset under the provisions of this Section shall |
6 | | recover all of the associated costs as set forth in this |
7 | | Section. After the Commission has approved the prudence and |
8 | | reasonableness of the costs that comprise the regulatory asset, |
9 | | the electric utility shall be permitted to recover all such |
10 | | costs, and the value and recoverability through rates of the |
11 | | associated regulatory asset shall not be limited, altered, |
12 | | impaired, or reduced. |
13 | | (f) Beginning in 2017, each electric utility shall file an |
14 | | energy efficiency plan with the Commission to meet the energy |
15 | | efficiency standards for the next applicable multi-year period |
16 | | beginning January 1 of the year following the filing, according |
17 | | to the schedule set forth in paragraphs (1) through (3) of this |
18 | | subsection (f). If a utility does not file such a plan on or |
19 | | before the applicable filing deadline for the plan, it shall |
20 | | face a penalty of $100,000 per day until the plan is filed. |
21 | | (1) No later than 30 days after June 1, 2017 ( the |
22 | | effective date of Public Act 99-906) this amendatory Act of |
23 | | the 99th General Assembly or May 1, 2017, whichever is |
24 | | later , each electric utility shall file a 4-year energy |
25 | | efficiency plan commencing on January 1, 2018 that is |
26 | | designed to achieve the cumulative persisting annual |
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1 | | savings goals specified in paragraphs (1) through (4) of |
2 | | subsection (b-5) of this Section or in paragraphs (1) |
3 | | through (4) of subsection (b-15) of this Section, as |
4 | | applicable, through implementation of energy efficiency |
5 | | measures; however, the goals may be reduced if the |
6 | | utility's expenditures are limited pursuant to subsection |
7 | | (m) of this Section or, for a utility that serves less than |
8 | | 3,000,000 retail customers, if each of the following |
9 | | conditions are met: (A) the plan's analysis and forecasts |
10 | | of the utility's ability to acquire energy savings |
11 | | demonstrate that achievement of such goals is not cost |
12 | | effective; and (B) the amount of energy savings achieved by |
13 | | the utility as determined by the independent evaluator for |
14 | | the most recent year for which savings have been evaluated |
15 | | preceding the plan filing was less than the average annual |
16 | | amount of savings required to achieve the goals for the |
17 | | applicable 4-year plan period. Except as provided in |
18 | | subsection (m) of this Section, annual increases in |
19 | | cumulative persisting annual savings goals during the |
20 | | applicable 4-year plan period shall not be reduced to |
21 | | amounts that are less than the maximum amount of cumulative |
22 | | persisting annual savings that is forecast to be |
23 | | cost-effectively achievable during the 4-year plan period. |
24 | | The Commission shall review any proposed goal reduction as |
25 | | part of its review and approval of the utility's proposed |
26 | | plan. |
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1 | | (2) No later than March 1, 2021, each electric utility |
2 | | shall file a 4-year energy efficiency plan commencing on |
3 | | January 1, 2022 that is designed to achieve the cumulative |
4 | | persisting annual savings goals specified in paragraphs |
5 | | (5) through (8) of subsection (b-5) of this Section or in |
6 | | paragraphs (5) through (8) of subsection (b-15) of this |
7 | | Section, as applicable, through implementation of energy |
8 | | efficiency measures; however, the goals may be reduced if |
9 | | the utility's expenditures are limited pursuant to |
10 | | subsection (m) of this Section or, each of the following |
11 | | conditions are met: (A) the plan's analysis and forecasts |
12 | | of the utility's ability to acquire energy savings |
13 | | demonstrate by clear and convincing evidence that |
14 | | achievement of such goals is not cost effective; and (B) |
15 | | the amount of energy savings achieved by the utility as |
16 | | determined by the independent evaluator for the most recent |
17 | | year for which savings have been evaluated preceding the |
18 | | plan filing was less than the average annual amount of |
19 | | savings required to achieve the goals for the applicable |
20 | | 4-year plan period. Except as provided in subsection (m) of |
21 | | this Section, annual increases in cumulative persisting |
22 | | annual savings goals during the applicable 4-year plan |
23 | | period shall not be reduced to amounts that are less than |
24 | | the maximum amount of cumulative persisting annual savings |
25 | | that is forecast to be cost-effectively achievable during |
26 | | the 4-year plan period. The Commission shall review any |
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1 | | proposed goal reduction as part of its review and approval |
2 | | of the utility's proposed plan , taking into account the |
3 | | results of the potential study required by subsection |
4 | | (f-5)of this Section . |
5 | | (3) No later than March 1, 2025, each electric utility |
6 | | shall file a 4-year 5-year energy efficiency plan |
7 | | commencing on January 1, 2026 that is designed to achieve |
8 | | the cumulative persisting annual savings goals specified |
9 | | in paragraphs (9) through (12) (13) of subsection (b-5) of |
10 | | this Section or in paragraphs (9) through (12) (13) of |
11 | | subsection (b-15) of this Section, as applicable, through |
12 | | implementation of energy efficiency measures; however, the |
13 | | goals may be reduced if the utility's expenditures are |
14 | | limited pursuant to subsection (m) of this Section or, each |
15 | | of the following conditions are met: (A) the plan's |
16 | | analysis and forecasts of the utility's ability to acquire |
17 | | energy savings demonstrate by clear and convincing |
18 | | evidence that achievement of such goals is not cost |
19 | | effective; and (B) the amount of energy savings achieved by |
20 | | the utility as determined by the independent evaluator for |
21 | | the most recent year for which savings have been evaluated |
22 | | preceding the plan filing was less than the average annual |
23 | | amount of savings required to achieve the goals for the |
24 | | applicable 4-year 5-year plan period. Except as provided in |
25 | | subsection (m) of this Section, annual increases in |
26 | | cumulative persisting annual savings goals during the |
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1 | | applicable 4-year 5-year plan period shall not be reduced |
2 | | to amounts that are less than the maximum amount of |
3 | | cumulative persisting annual savings that is forecast to be |
4 | | cost-effectively achievable during the 4-year 5-year plan |
5 | | period. The Commission shall review any proposed goal |
6 | | reduction as part of its review and approval of the |
7 | | utility's proposed plan , taking into account the results of |
8 | | the potential study required by subsection (f-5)of this |
9 | | Section . |
10 | | (4) No later than March 1, 2029, and every 4 years |
11 | | thereafter, each electric utility shall file a 4-year |
12 | | energy efficiency plan commencing on January 1, 2030, and |
13 | | every 4 years thereafter, respectively, that is designed to |
14 | | achieve the cumulative persisting annual savings goals |
15 | | established by the Illinois Commerce Commission pursuant |
16 | | to direction of subsections (b-5) and (b-15) of this |
17 | | Section, as applicable, through implementation of energy |
18 | | efficiency measures; however, the goals may be reduced if |
19 | | the utility's expenditures are limited pursuant to |
20 | | subsection (m) of this Section or, each of the following |
21 | | conditions are met: (A) the plan's analysis and forecasts |
22 | | of the utility's ability to acquire energy savings |
23 | | demonstrate by clear and convincing evidence that |
24 | | achievement of such goals is not cost effective; and (B) |
25 | | the amount of energy savings achieved by the utility as |
26 | | determined by the independent evaluator for the most recent |
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1 | | year for which savings have been evaluated preceding the |
2 | | plan filing was less than the average annual amount of |
3 | | savings required to achieve the goals for the applicable |
4 | | 4-year plan period. Except as provided in subsection (m) of |
5 | | this Section, annual increases in cumulative persisting |
6 | | annual savings goals during the applicable 4-year plan |
7 | | period shall not be reduced to amounts that are less than |
8 | | the maximum amount of cumulative persisting annual savings |
9 | | that is forecast to be cost-effectively achievable during |
10 | | the 4-year plan period. The Commission shall review any |
11 | | proposed goal reduction as part of its review and approval |
12 | | of the utility's proposed plan. |
13 | | Each utility's plan shall set forth the utility's proposals |
14 | | to meet the energy efficiency standards identified in |
15 | | subsection (b-5) or (b-15), as applicable and as such standards |
16 | | may have been modified under this subsection (f), taking into |
17 | | account the unique circumstances of the utility's service |
18 | | territory and results of an energy efficiency potential study |
19 | | as described in subsection (f-5) of this Section . For those |
20 | | plans commencing on January 1, 2018, the Commission shall seek |
21 | | public comment on the utility's plan and shall issue an order |
22 | | approving or disapproving each plan no later than August 31, |
23 | | 2017, or 105 days after June 1, 2017 ( the effective date of |
24 | | Public Act 99-906) this amendatory Act of the 99th General |
25 | | Assembly, whichever is later . For those plans commencing after |
26 | | December 31, 2021, the Commission shall seek public comment on |
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1 | | the utility's plan and shall issue an order approving or |
2 | | disapproving each plan within 6 months after its submission. If |
3 | | the Commission disapproves a plan, the Commission shall, within |
4 | | 30 days, describe in detail the reasons for the disapproval and |
5 | | describe a path by which the utility may file a revised draft |
6 | | of the plan to address the Commission's concerns |
7 | | satisfactorily. If the utility does not refile with the |
8 | | Commission within 60 days, the utility shall be subject to |
9 | | penalties at a rate of $100,000 per day until the plan is |
10 | | filed. This process shall continue, and penalties shall accrue, |
11 | | until the utility has successfully filed a portfolio of energy |
12 | | efficiency and demand-response measures. Penalties shall be |
13 | | deposited into the Energy Efficiency Trust Fund. |
14 | | (f-5) Energy efficiency potential study. An energy |
15 | | efficiency potential study shall be commissioned and overseen |
16 | | by the Illinois Commerce Commission. The potential study shall |
17 | | be reviewed as part of the approval of a utility's plan filed |
18 | | pursuant to subsection (f) of this Section. The potential study |
19 | | shall be designed and conducted with input from a Potential |
20 | | Study Stakeholder Committee established by the Commission. |
21 | | This Committee shall be comprised of representatives from each |
22 | | electric utility, the Illinois Attorney General's office, at |
23 | | least 2 environmental stakeholders, at least one community |
24 | | based organization, and additional parties representing |
25 | | consumers. The Committee shall provide input, at a minimum, |
26 | | into the scope of work for the studies, the selection of |
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1 | | vendors to perform the studies in accordance with appropriate |
2 | | confidentiality and conflict of interest provisions, and draft |
3 | | work products. The Committee shall make best efforts to achieve |
4 | | consensus on the key elements of the potential study, |
5 | | including: |
6 | | (i) savings potential from efficiency measures and |
7 | | program concepts that are known at the time of the study; |
8 | | (ii) likely emergence of new technology or new program |
9 | | concepts that could emerge; |
10 | | (iii) likely savings potential from efficiency |
11 | | measures that may be unique to individual industries or |
12 | | individual facilities; and |
13 | | (iv) the experience of other similar utilities, areas |
14 | | and jurisdictions in maximizing achievement of |
15 | | cost-effective savings. |
16 | | When the Committee is not able to reach consensus, the |
17 | | Commission shall make the final decision. |
18 | | (g) In submitting proposed plans and funding levels under |
19 | | subsection (f) of this Section to meet the savings goals |
20 | | identified in subsection (b-5) or (b-15) of this Section, as |
21 | | applicable, the utility shall: |
22 | | (1) Demonstrate that its proposed energy efficiency |
23 | | measures will achieve the applicable requirements that are |
24 | | identified in subsection (b-5) or (b-15) of this Section, |
25 | | as modified by subsection (f) of this Section. |
26 | | (2) Present specific proposals to implement new |
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1 | | building and appliance standards that have been placed into |
2 | | effect. |
3 | | (3) Demonstrate that its overall portfolio of |
4 | | measures, not including low-income programs described in |
5 | | subsection (c) of this Section, is cost-effective using the |
6 | | total resource cost test or complies with paragraphs (1) |
7 | | through (3) of subsection (f) of this Section and |
8 | | represents a diverse cross-section of opportunities for |
9 | | customers of all rate classes, other than those customers |
10 | | described in subsection (l) of this Section, to participate |
11 | | in the programs. Individual measures need not be cost |
12 | | effective. |
13 | | (3.5) Demonstrate that the utility's plan integrates |
14 | | the delivery of energy efficiency programs with natural gas |
15 | | efficiency programs, programs promoting distributed solar, |
16 | | programs promoting demand response and other efforts to |
17 | | address bill payment issues, including, but not limited to, |
18 | | LIHEAP and the Percent Income Payment Plan, to the extent |
19 | | such integration is practical and has the potential to |
20 | | enhance customer engagement, minimize market confusion, or |
21 | | reduce administrative costs. |
22 | | (4) Present a third-party energy efficiency |
23 | | implementation program subject to the following |
24 | | requirements: |
25 | | (A) beginning with the year commencing January 1, |
26 | | 2019, electric utilities that serve more than |
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1 | | 3,000,000 retail customers in the State shall fund |
2 | | third-party energy efficiency programs in an amount |
3 | | that is no less than $25,000,000 per year, and electric |
4 | | utilities that serve less than 3,000,000 retail |
5 | | customers but more than 500,000 retail customers in the |
6 | | State shall fund third-party energy efficiency |
7 | | programs in an amount that is no less than $8,350,000 |
8 | | per year; |
9 | | (B) during 2018, the utility shall conduct a |
10 | | solicitation process for purposes of requesting |
11 | | proposals from third-party vendors for those |
12 | | third-party energy efficiency programs to be offered |
13 | | during one or more of the years commencing January 1, |
14 | | 2019, January 1, 2020, and January 1, 2021; for those |
15 | | multi-year plans commencing on January 1, 2022 and |
16 | | January 1, 2026, the utility shall conduct a |
17 | | solicitation process during 2021 and 2025, |
18 | | respectively, for purposes of requesting proposals |
19 | | from third-party vendors for those third-party energy |
20 | | efficiency programs to be offered during one or more |
21 | | years of the respective multi-year plan period; for |
22 | | each solicitation process, the utility shall identify |
23 | | the sector, technology, or geographical area for which |
24 | | it is seeking requests for proposals; the solicitation |
25 | | process must be either for programs that fill gaps in |
26 | | the utility's program portfolio or for programs that |
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1 | | target business sectors, building types, geographies, |
2 | | or other specific parts of its customer base with |
3 | | initiatives that would be more effective at reaching |
4 | | these customer segments than the utilities' programs |
5 | | filed in its energy efficiency plans. |
6 | | (C) the utility shall propose the bidder |
7 | | qualifications, performance measurement process, and |
8 | | contract structure, which must include a performance |
9 | | payment mechanism and general terms and conditions; |
10 | | the proposed qualifications, process, and structure |
11 | | shall be subject to Commission approval; and |
12 | | (D) the utility shall retain an independent third |
13 | | party to score the proposals received through the |
14 | | solicitation process described in this paragraph (4), |
15 | | rank them according to their cost per lifetime |
16 | | kilowatt-hours saved, and assemble the portfolio of |
17 | | third-party programs. |
18 | | The electric utility shall recover all costs |
19 | | associated with Commission-approved, third-party |
20 | | administered programs regardless of the success of those |
21 | | programs. |
22 | | (4.5) Implement cost-effective demand-response |
23 | | measures to reduce peak demand by 0.1% over the prior year |
24 | | for eligible retail customers, as defined in Section |
25 | | 16-111.5 of this Act, and for customers that elect hourly |
26 | | service from the utility pursuant to Section 16-107 of this |
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1 | | Act, provided those customers have not been declared |
2 | | competitive. This requirement continues until December 31, |
3 | | 2026. |
4 | | (5) Include a proposed or revised cost-recovery tariff |
5 | | mechanism, as provided for under subsection (d) of this |
6 | | Section, to fund the proposed energy efficiency and |
7 | | demand-response measures and to ensure the recovery of the |
8 | | prudently and reasonably incurred costs of |
9 | | Commission-approved programs. |
10 | | (6) Provide for an annual independent evaluation of the |
11 | | performance of the cost-effectiveness of the utility's |
12 | | portfolio of measures, as well as a full review of the |
13 | | multi-year plan results of the broader net program impacts |
14 | | and, to the extent practical, for adjustment of the |
15 | | measures on a going-forward basis as a result of the |
16 | | evaluations. The resources dedicated to evaluation shall |
17 | | not exceed 3% of portfolio resources in any given year. |
18 | | (7) For electric utilities that serve more than |
19 | | 3,000,000 retail customers in the State: |
20 | | (A) Through December 31, 2025, provide for an |
21 | | adjustment to the return on equity component of the |
22 | | utility's weighted average cost of capital calculated |
23 | | under subsection (d) of this Section: |
24 | | (i) If the independent evaluator determines |
25 | | that the utility achieved a cumulative persisting |
26 | | annual savings that is less than the applicable |
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1 | | annual incremental goal, then the return on equity |
2 | | component shall be reduced by a maximum of 200 |
3 | | basis points in the event that the utility achieved |
4 | | no more than 75% of such goal. If the utility |
5 | | achieved more than 75% of the applicable annual |
6 | | incremental goal but less than 100% of such goal, |
7 | | then the return on equity component shall be |
8 | | reduced by 8 basis points for each percent by which |
9 | | the utility failed to achieve the goal. |
10 | | (ii) If the independent evaluator determines |
11 | | that the utility achieved a cumulative persisting |
12 | | annual savings that is more than the applicable |
13 | | annual incremental goal, then the return on equity |
14 | | component shall be increased by a maximum of 200 |
15 | | basis points in the event that the utility achieved |
16 | | at least 125% of such goal. If the utility achieved |
17 | | more than 100% of the applicable annual |
18 | | incremental goal but less than 125% of such goal, |
19 | | then the return on equity component shall be |
20 | | increased by 8 basis points for each percent by |
21 | | which the utility achieved above the goal. If the |
22 | | applicable annual incremental goal was reduced |
23 | | under paragraphs (1) or (2) of subsection (f) of |
24 | | this Section, then the following adjustments shall |
25 | | be made to the calculations described in this item |
26 | | (ii): |
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1 | | (aa) the calculation for determining |
2 | | achievement that is at least 125% of the |
3 | | applicable annual incremental goal shall use |
4 | | the unreduced applicable annual incremental |
5 | | goal to set the value; and |
6 | | (bb) the calculation for determining |
7 | | achievement that is less than 125% but more |
8 | | than 100% of the applicable annual incremental |
9 | | goal shall use the reduced applicable annual |
10 | | incremental goal to set the value for 100% |
11 | | achievement of the goal and shall use the |
12 | | unreduced goal to set the value for 125% |
13 | | achievement. The 8 basis point value shall also |
14 | | be modified, as necessary, so that the 200 |
15 | | basis points are evenly apportioned among each |
16 | | percentage point value between 100% and 125% |
17 | | achievement. |
18 | | (B) For the period January 1, 2026 through December |
19 | | 31, 2029 and in all subsequent 4-year periods 2030 , |
20 | | provide for an adjustment to the return on equity |
21 | | component of the utility's weighted average cost of |
22 | | capital calculated under subsection (d) of this |
23 | | Section: |
24 | | (i) If the independent evaluator determines |
25 | | that the utility achieved a cumulative persisting |
26 | | annual savings that is less than the applicable |
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1 | | annual incremental goal, then the return on equity |
2 | | component shall be reduced by a maximum of 200 |
3 | | basis points in the event that the utility achieved |
4 | | no more than 66% of such goal. If the utility |
5 | | achieved more than 66% of the applicable annual |
6 | | incremental goal but less than 100% of such goal, |
7 | | then the return on equity component shall be |
8 | | reduced by 6 basis points for each percent by which |
9 | | the utility failed to achieve the goal. |
10 | | (ii) If the independent evaluator determines |
11 | | that the utility achieved a cumulative persisting |
12 | | annual savings that is more than the applicable |
13 | | annual incremental goal, then the return on equity |
14 | | component shall be increased by a maximum of 200 |
15 | | basis points in the event that the utility achieved |
16 | | at least 134% of such goal. If the utility achieved |
17 | | more than 100% of the applicable annual |
18 | | incremental goal but less than 134% of such goal, |
19 | | then the return on equity component shall be |
20 | | increased by 6 basis points for each percent by |
21 | | which the utility achieved above the goal. If the |
22 | | applicable annual incremental goal was reduced |
23 | | under paragraph (3) of subsection (f) of this |
24 | | Section, then the following adjustments shall be |
25 | | made to the calculations described in this item |
26 | | (ii): |
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1 | | (aa) the calculation for determining |
2 | | achievement that is at least 134% of the |
3 | | applicable annual incremental goal shall use |
4 | | the unreduced applicable annual incremental |
5 | | goal to set the value; and |
6 | | (bb) the calculation for determining |
7 | | achievement that is less than 134% but more |
8 | | than 100% of the applicable annual incremental |
9 | | goal shall use the reduced applicable annual |
10 | | incremental goal to set the value for 100% |
11 | | achievement of the goal and shall use the |
12 | | unreduced goal to set the value for 134% |
13 | | achievement. The 6 basis point value shall also |
14 | | be modified, as necessary, so that the 200 |
15 | | basis points are evenly apportioned among each |
16 | | percentage point value between 100% and 134% |
17 | | achievement. |
18 | | (C) Notwithstanding the provisions of |
19 | | subparagraphs (A) and (B) of this paragraph (7), if the |
20 | | applicable annual incremental goal for an electric |
21 | | utility is ever less than 0.6% of deemed average |
22 | | weather normalized sales of electric power and energy |
23 | | during calendar years 2014, 2015, and 2016, an |
24 | | adjustment to the return on equity component of the |
25 | | utility's weighted average cost of capital calculated |
26 | | under subsection (d) of this Section shall be made as |
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1 | | follows: |
2 | | (i) If the independent evaluator determines |
3 | | that the utility achieved a cumulative persisting |
4 | | annual savings that is less than would have been |
5 | | achieved had the applicable annual incremental |
6 | | goal been achieved, then the return on equity |
7 | | component shall be reduced by a maximum of 200 |
8 | | basis points if the utility achieved no more than |
9 | | 75% of its applicable annual total savings |
10 | | requirement as defined in paragraph (7.5) of this |
11 | | subsection. If the utility achieved more than 75% |
12 | | of the applicable annual total savings requirement |
13 | | but less than 100% of such goal, then the return on |
14 | | equity component shall be reduced by 8 basis points |
15 | | for each percent by which the utility failed to |
16 | | achieve the goal. |
17 | | (ii) If the independent evaluator determines |
18 | | that the utility achieved a cumulative persisting |
19 | | annual savings that is more than would have been |
20 | | achieved had the applicable annual incremental |
21 | | goal been achieved, then the return on equity |
22 | | component shall be increased by a maximum of 200 |
23 | | basis points if the utility achieved at least 125% |
24 | | of its applicable annual total savings |
25 | | requirement. If the utility achieved more than |
26 | | 100% of the applicable annual total savings |
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1 | | requirement but less than 125% of such goal, then |
2 | | the return on equity component shall be increased |
3 | | by 8 basis points for each percent by which the |
4 | | utility achieved above the applicable annual total |
5 | | savings requirement. If the applicable annual |
6 | | incremental goal was reduced under paragraphs (1) |
7 | | or (2) of subsection (f) of this Section, then the |
8 | | following adjustments shall be made to the |
9 | | calculations described in this item (ii): |
10 | | (aa) the calculation for determining |
11 | | achievement that is at least 125% of the |
12 | | applicable annual total savings requirement |
13 | | shall use the unreduced applicable annual |
14 | | incremental goal to set the value; and |
15 | | (bb) the calculation for determining |
16 | | achievement that is less than 125% but more |
17 | | than 100% of the Applicable Annual Total |
18 | | Savings Requirement shall use the reduced |
19 | | applicable annual incremental goal to set the |
20 | | value for 100% achievement of the goal and |
21 | | shall use the unreduced goal to set the value |
22 | | for 125% achievement. The 8 basis point value |
23 | | shall also be modified, as necessary, so that |
24 | | the 200 basis points are evenly apportioned |
25 | | among each percentage point value between 100% |
26 | | and 125% achievement. |
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1 | | (7.5) For purposes of this Section, the term |
2 | | "applicable
annual incremental goal" means the difference |
3 | | between the
cumulative persisting annual savings goal for |
4 | | the calendar
year that is the subject of the independent |
5 | | evaluator's
determination and the cumulative persisting |
6 | | annual savings
goal for the immediately preceding calendar |
7 | | year, as such
goals are defined in subsections (b-5) and |
8 | | (b-15) of this
Section and as these goals may have been |
9 | | modified as
provided for under subsection (b-20) and |
10 | | paragraphs (1)
through (3) of subsection (f) of this |
11 | | Section. Under
subsections (b), (b-5), (b-10), and (b-15) |
12 | | of this Section,
a utility must first replace energy |
13 | | savings from measures
that have reached the end of their |
14 | | measure lives and would
otherwise have to be replaced to |
15 | | meet the applicable
savings goals identified in subsection |
16 | | (b-5) or (b-15) of this Section before any progress towards |
17 | | achievement of its
applicable annual incremental goal may |
18 | | be counted.
Notwithstanding anything else set forth in this |
19 | | Section,
the difference between the actual annual |
20 | | incremental
savings achieved in any given year, including |
21 | | the
replacement of energy savings from measures that have
|
22 | | expired, and the applicable annual incremental goal shall
|
23 | | not affect adjustments to the return on equity for
|
24 | | subsequent calendar years under this subsection (g). |
25 | | As used in this Section, "applicable annual total |
26 | | savings requirement" means the sum of (i) the applicable |
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1 | | annual savings goal; plus (ii) the amount of new annual |
2 | | savings required to replace savings from efficiency |
3 | | measures that provided cumulative persisting annual |
4 | | savings in the previous year, including savings from |
5 | | programs in 2012 through 2017 for which savings are deemed |
6 | | in subsections (b) and (b-10), but which reached the end of |
7 | | their measure lives by the end of the previous year. |
8 | | (8) For electric utilities that serve less than |
9 | | 3,000,000 retail customers but more than 500,000 retail |
10 | | customers in the State: |
11 | | (A) Through December 31, 2025, the applicable |
12 | | annual incremental goal shall be compared to the annual |
13 | | incremental savings as determined by the independent |
14 | | evaluator. |
15 | | (i) The return on equity component shall be |
16 | | reduced by 8 basis points for each percent by which |
17 | | the utility did not achieve 84.4% of the applicable |
18 | | annual incremental goal. |
19 | | (ii) The return on equity component shall be |
20 | | increased by 8 basis points for each percent by |
21 | | which the utility exceeded 100% of the applicable |
22 | | annual incremental goal. |
23 | | (iii) The return on equity component shall not |
24 | | be increased or decreased if the annual |
25 | | incremental savings as determined by the |
26 | | independent evaluator is greater than 84.4% of the |
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1 | | applicable annual incremental goal and less than |
2 | | 100% of the applicable annual incremental goal. |
3 | | (iv) The return on equity component shall not |
4 | | be increased or decreased by an amount greater than |
5 | | 200 basis points pursuant to this subparagraph |
6 | | (A). |
7 | | (B) For the period of January 1, 2026 through |
8 | | December 31, 2029 and in all subsequent 4-year periods |
9 | | 2030 , the applicable annual incremental goal shall be |
10 | | compared to the annual incremental savings as |
11 | | determined by the independent evaluator. |
12 | | (i) The return on equity component shall be |
13 | | reduced by 6 basis points for each percent by which |
14 | | the utility did not achieve 100% of the applicable |
15 | | annual incremental goal. |
16 | | (ii) The return on equity component shall be |
17 | | increased by 6 basis points for each percent by |
18 | | which the utility exceeded 100% of the applicable |
19 | | annual incremental goal. |
20 | | (iii) The return on equity component shall not |
21 | | be increased or decreased by an amount greater than |
22 | | 200 basis points pursuant to this subparagraph |
23 | | (B). |
24 | | (C) Notwithstanding provisions in subparagraphs |
25 | | (A) and (B) of paragraph (7) of this subsection, if the |
26 | | applicable annual incremental goal for an electric |
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1 | | utility is ever less than 0.6% of deemed average |
2 | | weather normalized sales of electric power and energy |
3 | | during calendar years 2014, 2015 and 2016, an |
4 | | adjustment to the return on equity component of the |
5 | | utility's weighted average cost of capital calculated |
6 | | under subsection (d) of this Section shall be made as |
7 | | follows: |
8 | | (i) The return on equity component shall be |
9 | | reduced by 8 basis points for each percent by which |
10 | | the utility did not achieve 100% of the applicable |
11 | | annual total savings requirement. |
12 | | (ii) The return on equity component shall be |
13 | | increased by 8 basis points for each percent by |
14 | | which the utility exceeded 100% of the applicable |
15 | | annual total savings requirement. |
16 | | (iii) The return on equity component shall not |
17 | | be increased or decreased by an amount greater than |
18 | | 200 basis points pursuant to this subparagraph |
19 | | (C). |
20 | | (D) (C) If the applicable annual incremental goal |
21 | | was reduced under paragraphs (1), (2) , or (3) , or (4) |
22 | | of subsection (f) of this Section, then the following |
23 | | adjustments shall be made to the calculations |
24 | | described in subparagraphs (A) , and (B) , and (C) of |
25 | | this paragraph (8): |
26 | | (i) The calculation for determining |
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1 | | achievement that is at least 125% or 134%, as |
2 | | applicable, of the applicable annual incremental |
3 | | goal or the applicable annual total savings |
4 | | requirement, as applicable, shall use the |
5 | | unreduced applicable annual incremental goal to |
6 | | set the value. |
7 | | (ii) For the period through December 31, 2025, |
8 | | the calculation for determining achievement that |
9 | | is less than 125% but more than 100% of the |
10 | | applicable annual incremental goal or the |
11 | | applicable annual total savings requirement, as |
12 | | applicable, shall use the reduced applicable |
13 | | annual incremental goal to set the value for 100% |
14 | | achievement of the goal and shall use the unreduced |
15 | | goal to set the value for 125% achievement. The 8 |
16 | | basis point value shall also be modified, as |
17 | | necessary, so that the 200 basis points are evenly |
18 | | apportioned among each percentage point value |
19 | | between 100% and 125% achievement. |
20 | | (iii) For the period of January 1, 2026 through |
21 | | December 31, 2029 and all subsequent 4-year |
22 | | periods, the calculation for determining |
23 | | achievement that is less than 125% or 134%, as |
24 | | applicable, but more than 100% of the applicable |
25 | | annual incremental goal or the applicable annual |
26 | | total savings requirement, as applicable, shall |
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1 | | use the reduced applicable annual incremental goal |
2 | | to set the value for 100% achievement of the goal |
3 | | and shall use the unreduced goal to set the value |
4 | | for 125% achievement. The 6 or 8 basis point |
5 | | values, as applicable, shall also be modified, as |
6 | | necessary, so that the 200 basis points are evenly |
7 | | apportioned among each percentage point value |
8 | | between 100% and 125% or between 100% and 134% |
9 | | achievement, as applicable. 2030, the calculation |
10 | | for determining achievement that is less than 134% |
11 | | but more than 100% of the applicable annual |
12 | | incremental goal shall use the reduced applicable |
13 | | annual incremental goal to set the value for 100% |
14 | | achievement of the goal and shall use the unreduced |
15 | | goal to set the value for 125% achievement. The 6 |
16 | | basis point value shall also be modified, as |
17 | | necessary, so that the 200 basis points are evenly |
18 | | apportioned among each percentage point value |
19 | | between 100% and 134% achievement. |
20 | | (9) The utility shall submit the energy savings data to |
21 | | the independent evaluator no later than 30 days after the |
22 | | close of the plan year. The independent evaluator shall |
23 | | determine the cumulative persisting annual savings for a |
24 | | given plan year , as well as an estimate of job impacts and |
25 | | other macroeconomic impacts of the efficiency programs for |
26 | | that year, no later than 120 days after the close of the |
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1 | | plan year. The utility shall submit an informational filing |
2 | | to the Commission no later than 160 days after the close of |
3 | | the plan year that attaches the independent evaluator's |
4 | | final report identifying the cumulative persisting annual |
5 | | savings for the year and calculates, under paragraph (7) or |
6 | | (8) of this subsection (g), as applicable, any resulting |
7 | | change to the utility's return on equity component of the |
8 | | weighted average cost of capital applicable to the next |
9 | | plan year beginning with the January monthly billing period |
10 | | and extending through the December monthly billing period. |
11 | | However, if the utility recovers the costs incurred under |
12 | | this Section under paragraphs (2) and (3) of subsection (d) |
13 | | of this Section, then the utility shall not be required to |
14 | | submit such informational filing, and shall instead submit |
15 | | the information that would otherwise be included in the |
16 | | informational filing as part of its filing under paragraph |
17 | | (3) of such subsection (d) that is due on or before June 1 |
18 | | of each year. |
19 | | For those utilities that must submit the informational |
20 | | filing, the Commission may, on its own motion or by |
21 | | petition, initiate an investigation of such filing, |
22 | | provided, however, that the utility's proposed return on |
23 | | equity calculation shall be deemed the final, approved |
24 | | calculation on December 15 of the year in which it is filed |
25 | | unless the Commission enters an order on or before December |
26 | | 15, after notice and hearing, that modifies such |
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1 | | calculation consistent with this Section. |
2 | | The adjustments to the return on equity component |
3 | | described in paragraphs (7) and (8) of this subsection (g) |
4 | | shall be applied as described in such paragraphs through a |
5 | | separate tariff mechanism, which shall be filed by the |
6 | | utility under subsections (f) and (g) of this Section. |
7 | | (10) Electric utilities required to implement |
8 | | efficiency programs under subsections (b-5) and (b-15) |
9 | | shall report annually to the Illinois Commerce Commission |
10 | | and the General Assembly on how hiring, contracting, job |
11 | | training, and other practices related to its energy |
12 | | efficiency programs enhance the diversity of vendors |
13 | | working on such programs. These reports must include data |
14 | | on vendor and employee diversity. |
15 | | (h) No more than 6% of energy efficiency and |
16 | | demand-response program revenue may be allocated for research, |
17 | | development, or pilot deployment of new equipment or measures.
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18 | | (i) When practicable, electric utilities shall incorporate |
19 | | advanced metering infrastructure data into the planning, |
20 | | implementation, and evaluation of energy efficiency measures |
21 | | and programs, subject to the data privacy and confidentiality |
22 | | protections of applicable law. |
23 | | (j) The independent evaluator shall follow the guidelines |
24 | | and use the savings set forth in Commission-approved energy |
25 | | efficiency policy manuals and technical reference manuals, as |
26 | | each may be updated from time to time. Until such time as |
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1 | | measure life values for energy efficiency measures implemented |
2 | | for low-income households under subsection (c) of this Section |
3 | | are incorporated into such Commission-approved manuals, the |
4 | | low-income measures shall have the same measure life values |
5 | | that are established for same measures implemented in |
6 | | households that are not low-income households. |
7 | | (k) Notwithstanding any provision of law to the contrary, |
8 | | an electric utility subject to the requirements of this Section |
9 | | may file a tariff cancelling an automatic adjustment clause |
10 | | tariff in effect under this Section or Section 8-103, which |
11 | | shall take effect no later than one business day after the date |
12 | | such tariff is filed. Thereafter, the utility shall be |
13 | | authorized to defer and recover its expenditures incurred under |
14 | | this Section through a new tariff authorized under subsection |
15 | | (d) of this Section or in the utility's next rate case under |
16 | | Article IX or Section 16-108.5 of this Act, with interest at an |
17 | | annual rate equal to the utility's weighted average cost of |
18 | | capital as approved by the Commission in such case. If the |
19 | | utility elects to file a new tariff under subsection (d) of |
20 | | this Section, the utility may file the tariff within 10 days |
21 | | after June 1, 2017 ( the effective date of Public Act 99-906) |
22 | | this amendatory Act of the 99th General Assembly , and the cost |
23 | | inputs to such tariff shall be based on the projected costs to |
24 | | be incurred by the utility during the calendar year in which |
25 | | the new tariff is filed and that were not recovered under the |
26 | | tariff that was cancelled as provided for in this subsection. |
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1 | | Such costs shall include those incurred or to be incurred by |
2 | | the utility under its multi-year plan approved under |
3 | | subsections (f) and (g) of this Section, including, but not |
4 | | limited to, projected capital investment costs and projected |
5 | | regulatory asset balances with correspondingly updated |
6 | | depreciation and amortization reserves and expense. The |
7 | | Commission shall, after notice and hearing, approve, or approve |
8 | | with modification, such tariff and cost inputs no later than 75 |
9 | | days after the utility filed the tariff, provided that such |
10 | | approval, or approval with modification, shall be consistent |
11 | | with the provisions of this Section to the extent they do not |
12 | | conflict with this subsection (k). The tariff approved by the |
13 | | Commission shall take effect no later than 5 days after the |
14 | | Commission enters its order approving the tariff. |
15 | | No later than 60 days after the effective date of the |
16 | | tariff cancelling the utility's automatic adjustment clause |
17 | | tariff, the utility shall file a reconciliation that reconciles |
18 | | the moneys collected under its automatic adjustment clause |
19 | | tariff with the costs incurred during the period beginning June |
20 | | 1, 2016 and ending on the date that the electric utility's |
21 | | automatic adjustment clause tariff was cancelled. In the event |
22 | | the reconciliation reflects an under-collection, the utility |
23 | | shall recover the costs as specified in this subsection (k). If |
24 | | the reconciliation reflects an over-collection, the utility |
25 | | shall apply the amount of such over-collection as a one-time |
26 | | credit to retail customers' bills. |
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1 | | (l) (Blank). For the calendar years covered by a multi-year |
2 | | plan commencing after December 31, 2017, subsections (a) |
3 | | through (j) of this Section do not apply to any retail |
4 | | customers of an electric utility that serves more than |
5 | | 3,000,000 retail customers in the State and whose total highest |
6 | | 30 minute demand was more than 10,000 kilowatts, or any retail |
7 | | customers of an electric utility that serves less than |
8 | | 3,000,000 retail customers but more than 500,000 retail |
9 | | customers in the State and whose total highest 15 minute demand |
10 | | was more than 10,000 kilowatts. For purposes of this subsection |
11 | | (l), "retail customer" has the meaning set forth in Section |
12 | | 16-102 of this Act. A determination of whether this subsection |
13 | | is applicable to a customer shall be made for each multi-year |
14 | | plan beginning after December 31, 2017. The criteria for |
15 | | determining whether this subsection (l) is applicable to a |
16 | | retail customer shall be based on the 12 consecutive billing |
17 | | periods prior to the start of the first year of each such |
18 | | multi-year plan. |
19 | | (m) Notwithstanding the requirements of this Section, as |
20 | | part of a proceeding to approve a multi-year plan under |
21 | | subsections (f) and (g) of this Section if the multi-year plan |
22 | | has been designed to maximize savings, but does not meet the |
23 | | cost cap limitations of this subsection , the Commission shall |
24 | | reduce the amount of energy efficiency measures implemented for |
25 | | any single year, and whose costs are recovered under subsection |
26 | | (d) of this Section, by an amount necessary to limit the |
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1 | | estimated average net increase due to the cost of the measures |
2 | | to no more than |
3 | | (1) 3.5% for the each of the 4 years beginning January |
4 | | 1, 2018, |
5 | | (2) 3.75% for each of the 4 years beginning January 1, |
6 | | 2022, and |
7 | | (3) 4% for each of the 5 years beginning January 1, |
8 | | 2026, |
9 | | (4) 4.25% for the 5 years beginning January 1, 2031, |
10 | | and |
11 | | (5) 4.25% plus a 0.25% increase for every subsequent |
12 | | 5-year period, |
13 | | of the average amount paid per kilowatthour by residential |
14 | | eligible retail customers during calendar year 2015. An |
15 | | electric utility may spend up to 10% more in any year during an |
16 | | applicable multi-year plan period to cost-effectively achieve |
17 | | additional savings so long as the average over the applicable |
18 | | multi-year plan period does not exceed the percentages defined |
19 | | in items (1) through (5). To determine the total amount that |
20 | | may be spent by an electric utility in any single year, the |
21 | | applicable percentage of the average amount paid per |
22 | | kilowatthour shall be multiplied by the total amount of energy |
23 | | delivered by such electric utility in the calendar year 2015, |
24 | | adjusted to reflect the proportion of the utility's load |
25 | | attributable to customers who are exempt from subsections (a) |
26 | | through (j) of this Section under subsection (l) of this |
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1 | | Section . For purposes of this subsection (m), the amount paid |
2 | | per kilowatthour includes,
without limitation, estimated |
3 | | amounts paid for supply,
transmission, distribution, |
4 | | surcharges, and add-on taxes. For purposes of this Section, |
5 | | "eligible retail customers" shall have the meaning set forth in |
6 | | Section 16-111.5 of this Act. Once the Commission has approved |
7 | | a plan under subsections (f) and (g) of this Section, no |
8 | | subsequent rate impact determinations shall be made.
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9 | | (Source: P.A. 99-906, eff. 6-1-17; 100-840, eff. 8-13-18; |
10 | | revised 10-19-18.) |
11 | | (220 ILCS 5/8-104.1 new) |
12 | | Sec. 8-104.1. Gas utilities; annual savings goals. |
13 | | (a) It is the policy of the State that gas utilities are |
14 | | required to use cost-effective energy efficiency to reduce |
15 | | delivery load. Requiring investment in cost-effective energy |
16 | | efficiency will reduce direct and indirect costs to consumers |
17 | | by decreasing environmental impacts and by reducing the amount |
18 | | of natural gas that needs to be purchased and avoiding or |
19 | | delaying the need for new transmission, distribution, storage |
20 | | and other related infrastructure. It serves the public interest |
21 | | to allow gas utilities to recover costs for reasonably and |
22 | | prudently incurred expenditures for energy efficiency |
23 | | measures. |
24 | | (b) In this Section: |
25 | | "Energy efficiency" means measures that reduce the amount |
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1 | | of energy required to achieve a given end use. "Energy |
2 | | efficiency" also includes measures that reduce the total Btus |
3 | | of electricity and natural gas needed to meet the end use or |
4 | | uses. |
5 | | "Cost-effective" means that the measures satisfy the total |
6 | | resource cost test which, for purposes of this Section, means a |
7 | | standard that is met if, for an investment in energy |
8 | | efficiency, the benefit-cost ratio is greater than one. The |
9 | | benefit-cost ratio is the ratio of the net present value of the |
10 | | total benefits of the measures to the net present value of the |
11 | | total costs as calculated over the lifetime of the measures. |
12 | | The total resource cost test compares the sum of avoided |
13 | | natural gas utility costs, representing the benefits that |
14 | | accrue to the natural gas system and the participant in the |
15 | | delivery of those efficiency measures and including avoided |
16 | | costs associated with the use of electricity or other fuels, |
17 | | avoided cost associated with reduced water consumption, and |
18 | | avoided costs associated with reduced operation and |
19 | | maintenance costs, as well as other quantifiable societal |
20 | | benefits, to the sum of all incremental costs of end use |
21 | | measures (including both utility and participant |
22 | | contributions), plus costs to administer, deliver, and |
23 | | evaluate each demand-side measure, to quantify the net savings |
24 | | obtained by substituting demand-side measures for supply |
25 | | resources. In calculating avoided costs, reasonable estimates |
26 | | shall be included for financial costs likely to be imposed by |
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1 | | future regulation of emissions of greenhouse gases. In |
2 | | discounting future societal costs and benefits for the purpose |
3 | | of calculating net present values, a societal discount rate |
4 | | based on actual, long-term Treasury bond yields shall be used. |
5 | | The low-income measures described in subsection (f) of this |
6 | | Section shall not be required to meet the total resource cost |
7 | | test. |
8 | | "Cumulative persisting annual savings" means the total gas |
9 | | energy savings in a given year from measures installed in that |
10 | | year or in previous years, but no earlier than January 1, 2020, |
11 | | that are still operational and providing savings in that year |
12 | | because the measures have not yet reached the end of their |
13 | | useful lives. |
14 | | (c) This Section applies to all gas distribution utilities |
15 | | in the State for those multi-year plans that include energy |
16 | | efficiency programs commencing after December 31, 2019. |
17 | | (d) Beginning in 2020, gas utilities subject to this |
18 | | Section shall achieve the following cumulative persisting |
19 | | annual savings goals, as compared to a deemed baseline |
20 | | equivalent to the utility's average annual therm sales in 2016 |
21 | | through 2018 through the implementation of energy efficiency |
22 | | measures during the applicable year and in prior years, but no |
23 | | earlier than January 1, 2020: |
24 | | (1) 1.2% cumulative persisting annual savings for the |
25 | | year ending December 31, 2020; |
26 | | (2) 2.1% cumulative persisting annual savings for the |
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1 | | year ending December 31, 2021; |
2 | | (3) 3.0% cumulative persisting annual savings for the |
3 | | year ending December 31, 2022; |
4 | | (4) 3.9% cumulative persisting annual savings for the |
5 | | year ending December 31, 2023; |
6 | | (5) 4.8% cumulative persisting annual savings for the |
7 | | year ending December 31, 2024; |
8 | | (6) 5.7% cumulative persisting annual savings for the |
9 | | year ending December 31, 2025; |
10 | | (7) 6.6% cumulative persisting annual savings for the |
11 | | year ending December 31, 2026; |
12 | | (8) 7.4% cumulative persisting annual savings for the |
13 | | year ending December 31, 2027; |
14 | | (9) 8.2% cumulative persisting annual savings for the |
15 | | year ending December 31, 2028; |
16 | | (10) 9.0% cumulative persisting annual savings for the |
17 | | year ending December 31, 2029; |
18 | | (11) 9.8% cumulative persisting annual savings for the |
19 | | year ending December 31, 2030; |
20 | | (12) 10.6% cumulative persisting annual savings for |
21 | | the year ending December 31, 2031; |
22 | | (13) 11.4% cumulative persisting annual savings for |
23 | | the year ending December 31, 2032; |
24 | | (14) 12.1% cumulative persisting annual savings for |
25 | | the year ending December 31, 2033; |
26 | | (15) 12.8% cumulative persisting annual savings for |
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1 | | the year ending December 31, 2034; and |
2 | | (16) 13.5% cumulative persisting annual savings for |
3 | | the year ending December 31, 2035. |
4 | | No later than December 31, 2025, the Illinois Commerce |
5 | | Commission shall establish additional cumulative persisting |
6 | | annual savings goals for the years 2036 through 2040. The |
7 | | Commission shall also establish additional cumulative |
8 | | persisting annual savings goals every 5 years thereafter to |
9 | | ensure utilities always have goals that extend at least 11 |
10 | | years into the future. The cumulative persisting annual savings |
11 | | goals beyond the year 2035 shall increase by 0.6 percentage |
12 | | points per year absent a Commission decision to initiate a |
13 | | proceeding to consider establishing goals that increase by more |
14 | | or less than that amount. Such a proceeding must be conducted |
15 | | in accordance with the procedures described in subsection (f) |
16 | | of this Section. If such a proceeding is initiated, the |
17 | | cumulative persisting annual savings goals established by the |
18 | | Commission through that proceeding shall reflect the |
19 | | Commission's best estimate of the maximum amount of additional |
20 | | gas savings that are forecast to be cost-effectively achievable |
21 | | unless such best estimates would result in goals that represent |
22 | | less than 0.4 percentage point annual increases in total |
23 | | cumulative persisting annual savings. The Commission may only |
24 | | establish goals that represent less than 0.4 percentage point |
25 | | annual increases in cumulative persisting annual savings if it |
26 | | can demonstrate, based on clear and convincing evidence, that |
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1 | | 0.4 percentage point increases are not cost-effectively |
2 | | achievable. The Commission shall inform its decision based on |
3 | | an energy efficiency potential study which conforms to the |
4 | | requirements of subsection (j-5) of this Section. |
5 | | (e) If a gas utility jointly offers an energy efficiency |
6 | | measure or program with an electric utility under plans |
7 | | approved under this Section and Section 8-103B of this Act, the |
8 | | gas utility may continue offering the program, including the |
9 | | electric energy efficiency measures, if the electric utility |
10 | | discontinues funding the program. In that event, the energy |
11 | | savings value associated with such other fuels shall be |
12 | | converted to gas energy savings on an equivalent Btu basis for |
13 | | the premises. However, the gas utility shall prioritize |
14 | | programs for low-income residential customers to the extent |
15 | | practicable. A gas utility may recover the costs of offering |
16 | | the gas energy efficiency measures under this subsection (e). |
17 | | For those energy efficiency measures or programs that save |
18 | | both gas and other fuels but are not jointly offered with an |
19 | | electric utility under plans approved under this Section and |
20 | | Section 8-103B, the gas utility may count savings of fuels |
21 | | other than gas toward the achievement of its annual savings |
22 | | goal, and the energy savings value associated with such other |
23 | | fuels shall be converted to gas energy savings on an equivalent |
24 | | Btu basis at the premises. |
25 | | In no event shall more than 10% of each year's applicable |
26 | | annual total savings requirement as defined in paragraph (8) of |
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1 | | subsection (j) of this Section be met through savings of fuels |
2 | | other than gas. |
3 | | (f) Gas utilities are responsible for overseeing the |
4 | | design, development, and filing of energy efficiency plans with |
5 | | the Commission and may, as part of that implementation, |
6 | | outsource various aspects of program development and |
7 | | implementation. A minimum of 10% of the utility's entire |
8 | | portfolio funding level for a given year shall be used to |
9 | | procure cost-effective energy efficiency measures from units |
10 | | of local government, municipal corporations, school districts, |
11 | | public housing, community college districts, and |
12 | | nonprofit-owned buildings provided that a minimum percentage |
13 | | of available funds shall be used to procure energy efficiency |
14 | | from public housing, which percentage shall be equal to public |
15 | | housing's share of public building energy consumption. |
16 | | The utilities shall also implement energy efficiency |
17 | | measures targeted at low-income single-family and multi-family |
18 | | households, which, for purposes of this Section, shall be |
19 | | defined as households at or below 80% of area median income, |
20 | | and expenditures to implement the measures shall be no less |
21 | | than 20% of the utility's total efficiency portfolio budget. |
22 | | At least 70% of spending on measures in programs targeted |
23 | | at low-income households shall go toward measures that reduce |
24 | | space heating needs through improvements to the building |
25 | | envelope or heating distribution systems. Programs targeted at |
26 | | low-income households, which address single-family and |
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1 | | multi-family buildings shall be treated such that savings |
2 | | opportunities in each building type are approximately in |
3 | | proportional to the magnitude of cost-effective energy |
4 | | efficiency opportunities in these respective building types. |
5 | | Each gas utility shall assess opportunities to implement |
6 | | cost-effective energy efficiency measures and programs through |
7 | | a public housing authority or authorities located in its |
8 | | service territory. If such opportunities are identified, the |
9 | | utility shall propose such measures and programs to address the |
10 | | opportunities. Expenditures to address such opportunities |
11 | | shall be credited toward the minimum procurement and |
12 | | expenditure requirements set forth in this subsection (f). |
13 | | Implementation of energy efficiency measures and programs |
14 | | targeted at low-income households shall be contracted, when it |
15 | | is practical, to independent third parties that have |
16 | | demonstrated capabilities to serve such households, with a |
17 | | preference for not-for-profit entities and government agencies |
18 | | that have existing relationships with or experience serving |
19 | | low-income communities in the State. |
20 | | Each gas utility shall develop and implement reporting |
21 | | procedures that address and assist in determining the amount of |
22 | | energy savings that can be applied to the low-income |
23 | | procurement and expenditure requirements set forth in this |
24 | | subsection (f). |
25 | | The gas utilities shall participate in a low-income energy |
26 | | efficiency advisory committee designed to allow a variety of |
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1 | | stakeholders, especially those living or working in low-income |
2 | | communities, to assist in the design and evaluation of the |
3 | | low-income energy efficiency programs. The committee shall be |
4 | | comprised of the electric utilities subject to the requirements |
5 | | of Section 8-103B of this Act, the gas utilities subject to the |
6 | | requirements of this Section, the utilities' low-income energy |
7 | | efficiency implementation contractors, nonprofit |
8 | | organizations, community action agencies, advocacy groups, |
9 | | State and local governmental agencies, and representatives of |
10 | | community-based organizations. The committee shall be convened |
11 | | by an independent third-party facilitator and a |
12 | | community-based organization in a low-income community. There |
13 | | shall be a leadership committee comprised of a variety of |
14 | | stakeholders, with at least one community-based organization |
15 | | involved. Meetings shall include concrete opportunities for |
16 | | groups to provide meaningful input into plan design, mid-cycle |
17 | | changes, and evaluation throughout the year to help reduce |
18 | | litigation in future plan filings. All meetings must be |
19 | | accessible, with rotating locations, call-in options, and |
20 | | materials and agendas circulated well in advance. There shall |
21 | | also be opportunities for input outside of meetings from those |
22 | | with limited capacity and ability to attend, via one-on-one |
23 | | meetings, surveys, and calls. Meetings shall also include |
24 | | opportunities to bundle and coordinate low-income energy |
25 | | efficiency with Solar for All and energy assistance programs. |
26 | | Meetings shall include educational opportunities for |
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1 | | stakeholders to learn more about these additional offerings, |
2 | | and the committee shall assist in the figuring out the best |
3 | | methods for coordinated delivery and implementation of |
4 | | offerings when serving low-income communities. |
5 | | (g) At least 50% of the entire efficiency program portfolio |
6 | | budget shall be spent on efficiency measures that reduce the |
7 | | amount of space heating needs through improvements to the |
8 | | efficiency of building envelopes (including, but not limited |
9 | | to, insulation measures, efficient windows and air leakage |
10 | | reduction) or through improvements to systems for distributing |
11 | | heat (including, but not limited to, duct leakage reduction, |
12 | | duct insulation or pipe insulation) in buildings. Spending on |
13 | | efficient furnaces, efficient boilers, or other efficient |
14 | | heating systems is permitted within the efficiency program |
15 | | portfolio, but does not count toward this minimum requirement |
16 | | for spending on building envelope and heating distribution |
17 | | efficiencies. Spending on low-income building envelope |
18 | | measures or heating distribution system measures does count |
19 | | toward this requirement. The portion of portfolio spending on |
20 | | program marketing, training of installers, audits of |
21 | | buildings, inspections of work performed, and other |
22 | | administrative and technical expenses that are clearly tied to |
23 | | promotion or installation of building envelope or heating |
24 | | distribution system measures shall count toward this |
25 | | requirement. If this minimum requirement is not met, any |
26 | | performance incentive earned under paragraph (7) of subsection |
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1 | | (j) should be reduced by the percentage point level of |
2 | | shortfall in meeting this requirement; if the utility is |
3 | | subject to a performance penalty, then the magnitude of the |
4 | | penalty shall be increased by the percentage point shortfall in |
5 | | meeting this requirement. |
6 | | (h) Notwithstanding any other provision of law to the |
7 | | contrary, a utility providing approved energy efficiency |
8 | | measures in the State shall be permitted to recover all |
9 | | reasonable and prudently incurred costs of those measures from |
10 | | all retail customers, provided that nothing in this subsection |
11 | | (h) permits the double recovery of such costs from customers. |
12 | | (i) Beginning in 2019, each gas utility shall file an |
13 | | energy efficiency plan with the Commission to meet the energy |
14 | | efficiency standards for the next applicable multi-year period |
15 | | beginning January 1 of the year following the filing, according |
16 | | to the schedule set forth in paragraphs (1) through (5) of this |
17 | | subsection (i). If a utility does not file such a plan on or |
18 | | before the applicable filing deadline for the plan, it shall |
19 | | face a penalty of $100,000 per day until the plan is filed. |
20 | | (1) No later than 120 days after the effective date of |
21 | | this amendatory Act of the 101st General Assembly, each gas |
22 | | utility shall file an energy efficiency plan to supersede |
23 | | its previously filed energy efficiency plan for the year |
24 | | beginning January 1, 2020 that is designed to achieve the |
25 | | cumulative persisting annual savings goals specified in |
26 | | paragraphs (1) and (2) of subsection (d) of this Section |
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1 | | through implementation of energy efficiency measures. |
2 | | (2) No later March 1, 2021, each gas utility shall file |
3 | | a 4-year energy efficiency plan commencing on January 1, |
4 | | 2022 that is designed to achieve the cumulative persisting |
5 | | annual savings goals specified in paragraphs (3) through |
6 | | (6) of subsection (d) of this Section through |
7 | | implementation of energy efficiency measures; however, the |
8 | | goals may be reduced if each of the following conditions |
9 | | are met: (A) the plan's analysis and forecasts of the |
10 | | utility's ability to acquire energy savings demonstrate |
11 | | beyond a reasonable doubt that achievement of such goals is |
12 | | not cost-effective; and (B) the amount of energy savings |
13 | | planned to be achieved by the utility in 2021, as |
14 | | documented pursuant to paragraph (1) of this subsection (i) |
15 | | and approved by the Illinois Commerce Commission, was less |
16 | | than the average annual amount of savings required to |
17 | | achieve the goals for the applicable 4-year plan period. |
18 | | Annual increases in cumulative persisting annual savings |
19 | | goals during the applicable 4-year plan period shall not be |
20 | | reduced to amounts that are less than the maximum amount of |
21 | | cumulative persisting annual savings that is forecast to be |
22 | | cost-effectively achievable during the 4-year plan period. |
23 | | The Commission shall review any proposed goal reduction as |
24 | | part of its review and approval of the utility's proposed |
25 | | plan, taking into account the results of the potential |
26 | | study required by subsection (j-5) of this Section. |
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1 | | (3) No later than March 1, 2025, each gas utility shall |
2 | | file a 4-year energy efficiency plan commencing on January |
3 | | 1, 2026 that is designed to achieve the cumulative |
4 | | persisting annual savings goals specified in paragraphs |
5 | | (7) through (10) of subsection (d) of this Section through |
6 | | implementation of energy efficiency measures; however, the |
7 | | goals may be reduced if each of the following conditions |
8 | | are met: (A) the plan's analysis and forecasts of the |
9 | | utility's ability to acquire energy savings demonstrate |
10 | | beyond a reasonable doubt that achievement of such goals is |
11 | | not cost-effective; and (B) the amount of energy savings |
12 | | achieved by the utility as determined by the independent |
13 | | evaluator for the most recent year for which savings have |
14 | | been evaluated preceding the plan filing was less than the |
15 | | average annual amount of savings required to achieve the |
16 | | goals for the applicable 4-year plan period. Annual |
17 | | increases in cumulative persisting annual savings goals |
18 | | during the applicable 4-year plan period shall not be |
19 | | reduced to amounts that are less than the maximum amount of |
20 | | cumulative persisting annual savings that is forecast to be |
21 | | cost-effectively achievable during the 4-year plan period. |
22 | | The Commission shall review any proposed goal reduction as |
23 | | part of its review and approval of the utility's proposed |
24 | | plan, taking into account the results of the potential |
25 | | study required by subsection (j-5) of this Section. |
26 | | (4) No later than March 1, 2029, each gas utility shall |
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1 | | file a 4-year energy efficiency plan commencing on January |
2 | | 1, 2030 that is designed to achieve the cumulative |
3 | | persisting annual savings goals specified in paragraphs |
4 | | (11) through (14) of subsection (d) of this Section through |
5 | | implementation of energy efficiency measures; however, the |
6 | | goals may be reduced if each of the following conditions |
7 | | are met: (A) the plan's analysis and forecasts of the |
8 | | utility's ability to acquire energy savings demonstrate |
9 | | beyond a reasonable doubt that achievement of such goals is |
10 | | not cost-effective; and (B) the amount of energy savings |
11 | | achieved by the utility as determined by the independent |
12 | | evaluator for the most recent year for which savings have |
13 | | been evaluated preceding the plan filing was less than the |
14 | | average annual amount of savings required to achieve the |
15 | | goals for the applicable 4-year plan period. Annual |
16 | | increases in cumulative persisting annual savings goals |
17 | | during the applicable 4-year plan period shall not be |
18 | | reduced to amounts that are less than the maximum amount of |
19 | | cumulative persisting annual savings that is forecast to be |
20 | | cost-effectively achievable during the 4-year plan period. |
21 | | The Commission shall review any proposed goal reduction as |
22 | | part of its review and approval of the utility's proposed |
23 | | plan, taking into account the results of the potential |
24 | | study required by subsection (j-5) of this Section. |
25 | | (5) No later than March 1, beginning in 2033 and each 4 |
26 | | years afterwards, each gas utility shall file a 4-year |
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1 | | energy efficiency plan commencing on January 1, beginning |
2 | | in 2034 and each 4-year period afterwards, that is designed |
3 | | to achieve the cumulative persisting annual savings goals |
4 | | established by the Illinois Commerce Commission pursuant |
5 | | to direction of subsection (d) of this Section, through |
6 | | implementation of energy efficiency measures; however, the |
7 | | goals may be reduced if each of the following conditions |
8 | | are met: (A) the plan's analysis and forecasts of the |
9 | | utility's ability to acquire energy savings demonstrate |
10 | | beyond a reasonable doubt that achievement of such goals is |
11 | | not cost-effective; and (B) the amount of energy savings |
12 | | achieved by the utility as determined by the independent |
13 | | evaluator for the most recent year for which savings have |
14 | | been evaluated preceding the plan filing was less than the |
15 | | average annual amount of savings required to achieve the |
16 | | goals for the applicable 4-year plan period. Annual |
17 | | increases in cumulative persisting annual savings goals |
18 | | during the applicable 4-year plan period shall not be |
19 | | reduced to amounts that are less than the maximum amount of |
20 | | cumulative persisting annual savings that is forecast to be |
21 | | cost-effectively achievable during the 4-year plan period. |
22 | | The Commission shall review any proposed goal reduction as |
23 | | part of its review and approval of the utility's proposed |
24 | | plan, taking into account the results of the potential |
25 | | study required by subsection (j-5) of this Section. |
26 | | Each utility's plan shall set forth the utility's proposals |
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1 | | to meet the energy efficiency standards identified in |
2 | | subsection (d). For those plans commencing on January 1, 2021, |
3 | | the Commission shall seek public comment on the utility's plan |
4 | | and shall issue an order approving or disapproving each plan no |
5 | | later than August 31, 2020, or 105 days after the effective |
6 | | date of this amendatory Act of the 101st General Assembly, |
7 | | whichever is later. For those plans commencing after December |
8 | | 31, 2022, the Commission shall seek public comment on the |
9 | | utility's plan and shall issue an order approving or |
10 | | disapproving each plan within 6 months after its submission. If |
11 | | the Commission disapproves a plan, the Commission shall, within |
12 | | 30 days, describe in detail the reasons for the disapproval and |
13 | | describe a path by which the utility may file a revised draft |
14 | | of the plan to address the Commission's concerns |
15 | | satisfactorily. If the utility does not refile with the |
16 | | Commission within 60 days, the utility shall be subject to |
17 | | penalties at a rate of $100,000 per day until the plan is |
18 | | filed. This process shall continue, and penalties shall accrue, |
19 | | until the utility has successfully filed a portfolio of energy |
20 | | efficiency measures. Penalties shall be deposited into the |
21 | | Energy Efficiency Trust Fund. |
22 | | (j) In submitting proposed plans and funding levels under |
23 | | subsection (i) of this Section to meet the savings goals |
24 | | identified in subsection (d), the utility shall: |
25 | | (1) Demonstrate that its proposed energy efficiency |
26 | | measures will achieve the applicable requirements that are |
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1 | | identified in subsection (d) of this Section. |
2 | | (2) Present specific proposals to implement new |
3 | | building and appliance standards that have been placed into |
4 | | effect. |
5 | | (3) Demonstrate that its overall portfolio of |
6 | | measures, not including low-income programs described in |
7 | | subsection (f) of this Section, is cost-effective using the |
8 | | total resource cost test, complies with subsection (i) of |
9 | | this Section and represents a diverse cross-section of |
10 | | opportunities for customers of all rate classes, to |
11 | | participate in the programs. Individual measures need not |
12 | | be cost effective. |
13 | | (3.5) Demonstrate that the utility's plan integrates |
14 | | the delivery of energy efficiency programs with electric |
15 | | efficiency programs and other efforts to address bill |
16 | | payment issues, including, but not limited to, LIHEAP and |
17 | | the Percent Income Payment Plan, to the extent such |
18 | | integration is practical and has the potential to enhance |
19 | | customer engagement, minimize market confusion, or reduce |
20 | | administrative costs. |
21 | | (4) Present a third-party energy efficiency |
22 | | implementation program subject to the following |
23 | | requirements: |
24 | | (A) Beginning with the year commencing January 1, |
25 | | 2021, gas utilities shall fund third-party energy |
26 | | efficiency programs in an amount that is no less than |
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1 | | 10% of total efficiency portfolio budgets per year. |
2 | | (B) For multi-year plans commencing on January 1, |
3 | | 2022, January 1, 2026, January 1, 2030, and every 4 |
4 | | years thereafter, the utility shall conduct a |
5 | | solicitation process during 2021, 2025, 2029, and |
6 | | every 4 years thereafter, respectively, for purposes |
7 | | of requesting proposals from third-party vendors for |
8 | | those third-party energy efficiency programs to be |
9 | | offered during one or more years of the respective |
10 | | multi-year plan period; for each solicitation process, |
11 | | the utility shall identify the sector, technology, or |
12 | | geographical area for which it is seeking requests for |
13 | | proposals; the solicitation process must be for |
14 | | programs that fill gaps in the utility's program |
15 | | portfolio or targets business sectors, building types, |
16 | | geographies or other specific parts of its customer |
17 | | base with initiatives that would be more effective at |
18 | | reaching these customer segments than the utilities' |
19 | | programs filed in its energy efficiency plans. |
20 | | (C) The utility shall propose the bidder |
21 | | qualifications, performance measurement process, and |
22 | | contract structure, which must include a performance |
23 | | payment mechanism and general terms and conditions; |
24 | | the proposed qualifications, process, and structure |
25 | | shall be subject to Commission approval. |
26 | | (D) The utility shall retain an independent third |
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1 | | party to score the proposals received through the |
2 | | solicitation process described in this paragraph (4), |
3 | | rank them according to their cost per lifetime |
4 | | kilowatt-hours saved, and assemble the portfolio of |
5 | | third-party programs. |
6 | | The gas utility shall recover all costs associated with |
7 | | Commission-approved, third-party administered programs |
8 | | regardless of the success of those programs. |
9 | | (5) Include a proposed or revised cost-recovery |
10 | | mechanism, as provided for under subsection (h) of this |
11 | | Section, to fund the proposed energy efficiency measures |
12 | | and to ensure the recovery of the prudently and reasonably |
13 | | incurred costs of Commission-approved programs. |
14 | | (6) Provide for an annual independent evaluation of the |
15 | | performance of the cost-effectiveness of the utility's |
16 | | portfolio of measures, as well as a full review of the |
17 | | multi-year plan results of the broader net program impacts |
18 | | and, to the extent practical, for adjustment of the |
19 | | measures on a going-forward basis as a result of the |
20 | | evaluations. The resources dedicated to evaluation shall |
21 | | not exceed 3% of portfolio resources in any given year. |
22 | | (7) Each gas utility shall be eligible to earn a |
23 | | shareholder incentive for effective implementation of its |
24 | | efficiency programs. The incentive shall be tied to each |
25 | | utility's annual energy efficiency spending and its |
26 | | savings relative to its applicable annual total savings |
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1 | | requirement as defined in paragraph (8) of this subsection |
2 | | (j). There shall be no incentive if the independent |
3 | | evaluator determines the utility failed to achieve savings |
4 | | equal to at least 75% of its applicable annual total |
5 | | savings requirement and an incentive equal 0.3% of total |
6 | | annual efficiency spending in the year being evaluated for |
7 | | every one percentage point above 75% of its applicable |
8 | | annual total savings requirement that the utility achieved |
9 | | in that year, with a maximum incentive of 15% for achieving |
10 | | 125% of its applicable annual total savings requirement. |
11 | | (7.5) In this Section, "applicable annual incremental |
12 | | goal" means the difference between the cumulative |
13 | | persisting annual savings goal for the calendar year that |
14 | | is the subject of the independent evaluator's |
15 | | determination and the cumulative persisting annual savings |
16 | | goal for the immediately preceding calendar year, as such |
17 | | goals are defined in subsection (d) of this Section. Under |
18 | | subsection (d) of this Section, a utility must first |
19 | | replace energy savings from measures that have reached the |
20 | | end of their measure lives and would otherwise have to be |
21 | | replaced to meet the applicable savings goals identified in |
22 | | subsection (d) of this Section before any progress toward |
23 | | achievement of its applicable annual incremental goal may |
24 | | be counted. Notwithstanding anything else set forth in this |
25 | | Section, the difference between the actual annual |
26 | | incremental savings achieved in any given year, including |
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1 | | the replacement of energy savings from measures that have |
2 | | expired, and the applicable annual incremental goal shall |
3 | | not affect adjustments to the return on equity for |
4 | | subsequent calendar years under this subsection (j). |
5 | | (8) In this Section, "Applicable Annual Total Savings |
6 | | Requirement" means the total amount of new annual savings |
7 | | that the utility must achieve in any given year to achieve |
8 | | the Applicable Annual Incremental Goal. This shall be equal |
9 | | to the Applicable Annual Incremental Savings Goal plus the |
10 | | total new annual savings that are required to replace |
11 | | savings from efficiency measures that provided cumulative |
12 | | persistent annual savings in the previous year but expired |
13 | | in or at the end of the previous year and are therefore no |
14 | | longer producing savings. |
15 | | (9) The utility shall submit the energy savings data to |
16 | | the independent evaluator no later than 30 days after the |
17 | | close of the plan year. The independent evaluator shall |
18 | | determine the cumulative persisting annual savings and the |
19 | | utility's performance relative to its Applicable Annual |
20 | | Total Savings Requirement for a given plan year no later |
21 | | than 120 days after the close of the plan year. The |
22 | | independent evaluator must also estimate the job impacts |
23 | | and other macroeconomic impacts of the utility's |
24 | | efficiency programs. The utility shall submit an |
25 | | informational filing to the Commission no later than 160 |
26 | | days after the close of the plan year that attaches the |
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1 | | independent evaluator's final report identifying the |
2 | | cumulative persisting annual savings for the year and |
3 | | calculates, under paragraph (7) of this subsection (j), as |
4 | | applicable, the magnitude of any shareholder incentive |
5 | | which the utility has earned. |
6 | | (10) Gas utilities shall report annually to the |
7 | | Illinois Commerce Commission and General Assembly on how |
8 | | hiring, contracting, job training, and other practices |
9 | | related to its energy efficiency programs enhance the |
10 | | diversity of vendors working on such programs. These |
11 | | reports must include data on vendor and employee diversity. |
12 | | (j-5) Energy efficiency potential study. An energy |
13 | | efficiency potential study shall be commissioned and overseen |
14 | | by the Illinois Commerce Commission. The potential study shall |
15 | | be reviewed as part of the approval of a utility's plan filed |
16 | | pursuant to subsection (f) of this Section. The potential study |
17 | | shall be designed and conducted with input from a Potential |
18 | | Study Stakeholder Committee established by the Commission. |
19 | | This Committee shall be comprised of representatives from each |
20 | | electric utility, the Illinois Attorney General's office, at |
21 | | least 2 environmental stakeholders, at least one |
22 | | community-based organization, and additional parties |
23 | | representing consumers. The Committee shall provide input, at a |
24 | | minimum, into the scope of work for the studies, the selection |
25 | | of vendors to perform the studies in accordance with |
26 | | appropriate confidentiality and conflict of interest |
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1 | | provisions, and draft work products. The Committee shall make |
2 | | best efforts to achieve consensus on the key elements of the |
3 | | potential study, including: |
4 | | (i) savings potential from efficiency measures and |
5 | | program concepts that are known at the time of the study; |
6 | | (ii) likely emergence of new technology or new program |
7 | | concepts that could emerge; |
8 | | (iii) likely savings potential from efficiency |
9 | | measures that may be unique to individual industries or |
10 | | individual facilities; and |
11 | | (iv) the experience of other similar utilities, areas |
12 | | and jurisdictions in maximizing achievement of |
13 | | cost-effective savings. |
14 | | When the committee is not able to reach consensus, the |
15 | | Commission shall make the final decision. |
16 | | (k) No more than 6% of energy efficiency and |
17 | | demand-response program revenue may be allocated for research, |
18 | | development, or pilot deployment of new equipment or measures. |
19 | | (l) When practical, gas utilities shall incorporate |
20 | | advanced metering infrastructure data into the planning, |
21 | | implementation, and evaluation of energy efficiency measures |
22 | | and programs, subject to the data privacy and confidentiality |
23 | | protections of applicable law. |
24 | | (m) The independent evaluator shall follow the guidelines |
25 | | and use the savings set forth in Commission-approved energy |
26 | | efficiency policy manuals and technical reference manuals, as |
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1 | | each may be updated from time to time. Until measure life |
2 | | values for energy efficiency measures implemented for |
3 | | low-income households under subsection (f) of this Section are |
4 | | incorporated into such Commission-approved manuals, the |
5 | | low-income measures shall have the same measure life values |
6 | | that are established for same measures implemented in |
7 | | households that are not low-income households. |
8 | | (220 ILCS 5/9-220.3) |
9 | | (Section scheduled to be repealed on December 31, 2023) |
10 | | Sec. 9-220.3. Natural gas surcharges authorized. |
11 | | (a) Tariff. |
12 | | (1) Pursuant to Section 9-201 of this Act, a natural |
13 | | gas utility serving more than 700,000 customers may file a |
14 | | tariff for a surcharge which adjusts rates and charges to |
15 | | provide for recovery of costs associated with investments |
16 | | in qualifying infrastructure plant, independent of any |
17 | | other matters related to the utility's revenue |
18 | | requirement. |
19 | | (2) Within 30 days after the effective date of this |
20 | | amendatory Act of the 98th General Assembly, the Commission |
21 | | shall adopt emergency rules to implement the provisions of |
22 | | this amendatory Act of the 98th General Assembly. The |
23 | | utility may file with the Commission tariffs implementing |
24 | | the provisions of this amendatory Act of the 98th General |
25 | | Assembly after the effective date of the emergency rules |
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1 | | authorized by subsection (i). |
2 | | (3) The Commission shall issue an order approving, or |
3 | | approving with modification to ensure compliance with this |
4 | | Section, the tariff no later than 120 days after such |
5 | | filing of the tariffs filed pursuant to this Section. The |
6 | | utility shall have 7 days following the date of service of |
7 | | the order to notify the Commission in writing whether it |
8 | | will accept any modifications so identified in the order or |
9 | | whether it has elected not to proceed with the tariff. If |
10 | | the order includes no modifications or if the utility |
11 | | notifies the Commission that it will accept such |
12 | | modifications, the tariff shall take effect on the first |
13 | | day of the calendar year in which the Commission issues the |
14 | | order, subject to petitions for rehearing and appellate |
15 | | procedures. After the tariff takes effect, the utility may, |
16 | | upon 10 days' notice to the Commission, file to withdraw |
17 | | the tariff at any time, and the Commission shall approve |
18 | | such filing without suspension or hearing, subject to a |
19 | | final reconciliation as provided in subsection (e) of this |
20 | | Section. |
21 | | (4) When a natural gas utility withdraws the surcharge |
22 | | tariff, the utility shall not recover any additional |
23 | | charges through the surcharge approved pursuant to this |
24 | | Section, subject to the resolution of the final |
25 | | reconciliation pursuant to subsection (e) of this Section. |
26 | | The utility's qualifying infrastructure investment net of |
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1 | | accumulated depreciation may be transferred to the natural |
2 | | gas utility's rate base in the utility's next general rate |
3 | | case. The utility's delivery base rates in effect upon |
4 | | withdrawal of the surcharge tariff shall not be adjusted at |
5 | | the time the surcharge tariff is withdrawn. |
6 | | (5) A natural gas utility that is subject to its |
7 | | delivery base rates being fixed at their current rates |
8 | | pursuant to a Commission order entered in Docket No. |
9 | | 11-0046, notwithstanding the effective date of its tariff |
10 | | authorized pursuant to this Section, shall reflect in a |
11 | | tariff surcharge only those projects placed in service |
12 | | after the fixed rate period of the merger agreement has |
13 | | expired by its terms. |
14 | | (b) For purposes of this Section, "qualifying |
15 | | infrastructure plant" includes only plant additions placed in |
16 | | service not reflected in the rate base used to establish the |
17 | | utility's delivery base rates. "Costs associated with |
18 | | investments in qualifying infrastructure plant" shall include |
19 | | a return on qualifying infrastructure plant and recovery of |
20 | | depreciation and amortization expense on qualifying |
21 | | infrastructure plant, net of the depreciation included in the |
22 | | utility's base rates on any plant retired in conjunction with |
23 | | the installation of the qualifying infrastructure plant. |
24 | | Collectively the "qualifying infrastructure plant" and "costs |
25 | | associated with investments in qualifying infrastructure |
26 | | plant" are referred to as the "qualifying infrastructure |
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1 | | investment" and that are related to one or more of the |
2 | | following: |
3 | | (1) the installation of facilities to retire and |
4 | | replace underground natural gas facilities, including |
5 | | facilities appurtenant to facilities constructed of those |
6 | | materials such as meters, regulators, and services, and |
7 | | that are constructed of cast iron, wrought iron, ductile |
8 | | iron, unprotected coated steel, unprotected bare steel, |
9 | | mechanically coupled steel, copper, Cellulose Acetate |
10 | | Butyrate (CAB) plastic, pre-1973 DuPont Aldyl "A" |
11 | | polyethylene, PVC, or other types of materials identified |
12 | | by a State or federal governmental agency as being prone to |
13 | | leakage; |
14 | | (2) the relocation of meters from inside customers' |
15 | | facilities to outside; |
16 | | (3) the upgrading of the gas distribution system from a |
17 | | low pressure to a medium pressure system, including |
18 | | installation of high-pressure facilities to support the |
19 | | upgrade; |
20 | | (4) modernization investments by a combination |
21 | | utility, as defined in subsection (b) of Section 16-108.5 |
22 | | of this Act, to install: |
23 | | (A) advanced gas meters in connection with the |
24 | | installation of advanced electric meters pursuant to |
25 | | Sections 16-108.5 and 16-108.6 of this Act; and |
26 | | (B) the communications hardware and software and |
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1 | | associated system software that creates a network |
2 | | between advanced gas meters and utility business |
3 | | systems and allows the collection and distribution of |
4 | | gas-related information to customers and other parties |
5 | | in addition to providing information to the utility |
6 | | itself; |
7 | | (5) replacing high-pressure transmission pipelines and |
8 | | associated facilities identified as having a higher risk of |
9 | | leakage or failure or installing or replacing |
10 | | high-pressure transmission pipelines and associated |
11 | | facilities to establish records and maximum allowable |
12 | | operating pressures; |
13 | | (6) replacing difficult to locate mains and service |
14 | | pipes and associated facilities; and |
15 | | (7) replacing or installing transmission and |
16 | | distribution regulator stations, regulators, valves, and |
17 | | associated facilities to establish over-pressure |
18 | | protection. |
19 | | With respect to the installation of the facilities |
20 | | identified in paragraph (1) of subsection (b) of this Section, |
21 | | the natural gas utility shall determine priorities for such |
22 | | installation with consideration of projects either: (i) |
23 | | integral to a general government public facilities improvement |
24 | | program or (ii) ranked in the highest risk categories in the |
25 | | utility's most recent Distribution Integrity Management Plan |
26 | | where removal or replacement is the remedial measure. |
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1 | | (c) Qualifying infrastructure investment, defined in |
2 | | subsection (b) of this Section, recoverable through a tariff |
3 | | authorized by subsection (a) of this Section, shall not include |
4 | | costs or expenses incurred in the ordinary course of business |
5 | | for the ongoing or routine operations of the utility, |
6 | | including, but not limited to: |
7 | | (1) operating and maintenance costs; and |
8 | | (2) costs of facilities that are revenue-producing, |
9 | | which means facilities that are constructed or installed |
10 | | for the purpose of serving new customers. |
11 | | (d) Gas utility commitments. A natural gas utility that has |
12 | | in effect a natural gas surcharge tariff pursuant to this |
13 | | Section shall: |
14 | | (1) recognize that the General Assembly identifies |
15 | | improved public safety and reliability of natural gas |
16 | | facilities as the cornerstone upon which this Section is |
17 | | designed, and qualifying projects should be encouraged, |
18 | | selected, and prioritized based on these factors; and |
19 | | (2) provide information to the Commission as requested |
20 | | to demonstrate that (i) the projects included in the tariff |
21 | | are indeed qualifying projects and (ii) the projects are |
22 | | selected and prioritized taking into account improved |
23 | | public safety and reliability. |
24 | | (3) The amount of qualifying infrastructure investment |
25 | | eligible for recovery under the tariff in the applicable |
26 | | calendar year is limited to the lesser of (i) the actual |
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1 | | qualifying infrastructure plant placed in service in the |
2 | | applicable calendar year and (ii) the difference by which |
3 | | total plant additions in the applicable calendar year |
4 | | exceed the baseline amount, and subject to the limitation |
5 | | in subsection (g) of this Section. A natural gas utility |
6 | | can recover the costs of qualifying infrastructure |
7 | | investments through an approved surcharge tariff from the |
8 | | beginning of each calendar year subject to the |
9 | | reconciliation initiated under paragraph (2) of subsection |
10 | | (e) of this Section, during which the Commission may make |
11 | | adjustments to ensure that the limits defined in this |
12 | | paragraph are not exceeded. Further, if total plant |
13 | | additions in a calendar year do not exceed the baseline |
14 | | amount in the applicable calendar year, the Commission, |
15 | | during the reconciliation initiated under paragraph (2) of |
16 | | subsection (e) of this Section for the applicable calendar |
17 | | year, shall adjust the amount of qualifying infrastructure |
18 | | investment eligible for recovery under the tariff to zero. |
19 | | (4) For purposes of this Section, "baseline amount" |
20 | | means an amount equal to the utility's average of total |
21 | | depreciation expense, as reported on page 336, column (b) |
22 | | of the utility's ILCC Form 21, for the calendar years 2006 |
23 | | through 2010. |
24 | | (e) Review of investment. |
25 | | (1) The amount of qualifying infrastructure investment |
26 | | shall be shown on an Information Sheet supplemental to the |
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1 | | surcharge tariff and filed with the Commission monthly or |
2 | | some other time period at the option of the utility. The |
3 | | Information Sheet shall be accompanied by data showing the |
4 | | calculation of the qualifying infrastructure investment |
5 | | adjustment. Unless otherwise ordered by the Commission, |
6 | | each qualifying infrastructure investment adjustment shown |
7 | | on an Information Sheet shall become effective pursuant to |
8 | | the utility's approved tariffs. |
9 | | (2) For each calendar year in which a surcharge tariff |
10 | | is in effect, the natural gas utility shall file a petition |
11 | | with the Commission to initiate hearings to reconcile |
12 | | amounts billed under each surcharge authorized pursuant to |
13 | | this Section with the actual prudently incurred costs |
14 | | recoverable under this tariff in the preceding year. The |
15 | | petition filed by the natural gas utility shall include |
16 | | testimony and schedules that support the accuracy and the |
17 | | prudence of the qualifying infrastructure investment for |
18 | | the calendar year being reconciled. The petition filed |
19 | | shall also include the number of jobs attributable to the |
20 | | natural gas surcharge tariff as required by rule. The |
21 | | review of the utility's investment shall include |
22 | | identification and review of all plant that was ranked |
23 | | within the highest risk categories in that utility's most |
24 | | recent Distribution Integrity Management Plan. |
25 | | (f) The rate of return applied shall be the overall rate of |
26 | | return authorized by the Commission in the utility's last gas |
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1 | | rate case. |
2 | | (g) The cumulative amount of increases billed under the |
3 | | surcharge, since the utility's most recent delivery service |
4 | | rate order, shall not exceed an annual average 4% of the |
5 | | utility's delivery base rate revenues, but shall not exceed |
6 | | 5.5% in any given year. On the effective date of new delivery |
7 | | base rates, the surcharge shall be reduced to zero with respect |
8 | | to qualifying infrastructure investment that is transferred to |
9 | | the rate base used to establish the utility's delivery base |
10 | | rates, provided that the utility may continue to charge or |
11 | | refund any reconciliation adjustment determined pursuant to |
12 | | subsection (e) of this Section. |
13 | | (h) If a gas utility obtains a surcharge tariff under this |
14 | | Section 9-220.3, then it and its affiliates are excused from |
15 | | the rate case filing requirements contained in Sections |
16 | | 9-220(h) and 9-220(h-1). In the event a natural gas utility, |
17 | | prior to the effective date of this amendatory Act of the 98th |
18 | | General Assembly, made a rate case filing that is still pending |
19 | | on the effective date of this amendatory Act of the 98th |
20 | | General Assembly, the natural gas utility may, at the time it |
21 | | files its surcharge tariff with the Commission, also file a |
22 | | notice with the Commission to withdraw its rate case filing. |
23 | | Any affiliate of such natural gas utility may also file to |
24 | | withdraw its rate case filing. Upon receipt of such notice, the |
25 | | Commission shall dismiss the rate case filing with prejudice |
26 | | and such tariffs and the record related thereto shall not be |
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1 | | the subject of any further hearing, investigation, or |
2 | | proceeding of any kind related to rates for gas delivery |
3 | | services. Notwithstanding the foregoing, a natural gas utility |
4 | | shall not be permitted to withdraw a rate case filing for which |
5 | | a proposed order recommending a rate reduction is pending. A |
6 | | natural gas utility shall not be permitted to withdraw the gas |
7 | | delivery services tariffs that are the subject of Commission |
8 | | Docket Nos. 12-0511/12-0512 (cons.). None of the costs incurred |
9 | | for the withdrawn rate case are recoverable from ratepayers. |
10 | | (i) The Commission shall promulgate rules and regulations |
11 | | to carry out the provisions of this Section under the emergency |
12 | | rulemaking provisions set forth in Section 5-45 of the Illinois |
13 | | Administrative Procedure Act, and such emergency rules shall be |
14 | | effective no later than 30 days after the effective date of |
15 | | this amendatory Act of the 98th General Assembly. |
16 | | (j) Utilities that have elected to recover qualifying |
17 | | infrastructure investment costs pursuant to this Section shall |
18 | | file annually their Distribution Integrity Management Plan |
19 | | (DIMP) with the Commission no later than June 1 of each year |
20 | | the utility has said tariff in effect. The DIMP shall include |
21 | | the following information: |
22 | | (1) Baseline Distribution System Data: Information |
23 | | such as demand, system pressures and flows, and metering |
24 | | infrastructure. |
25 | | (2) Financial Data: historical and projected spending |
26 | | on distribution system infrastructure. |
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1 | | (3) Scenario Analysis: Discussion of projected changes |
2 | | in usage over time. |
3 | | (4) Descriptions of all qualifying infrastructure |
4 | | investment proposed for the coming year. |
5 | | (k) Within 45 days after filing, the Commission shall, with |
6 | | reasonable notice, open an investigation to consider whether |
7 | | the Plan meets the objectives set forth in this subsection and |
8 | | contains the information required by subsection (j). The |
9 | | Commission shall issue a final order approving the Plan, with |
10 | | any modifications the Commission deems reasonable and |
11 | | appropriate to achieve the goals of this Section, within 270 |
12 | | days of the Plan filing. The investigation will assess whether |
13 | | the DIMP: |
14 | | (1) ensures optimized utilization of utility |
15 | | infrastructure assets and resources to minimize total |
16 | | system costs; |
17 | | (2) enables greater customer engagement, empowerment, |
18 | | and options for services; |
19 | | (3) to the maximum extent possible, achieves and or |
20 | | supports the achievement of greenhouse gas emissions |
21 | | reductions as described by Section 9.10 of the |
22 | | Environmental Protection Act; and |
23 | | (4) supports existing Illinois policy goals promoting |
24 | | energy efficiency. |
25 | | The Commission process shall maximize the sharing of |
26 | | information, ensure robust stakeholder participation, and |
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1 | | recognize the responsibility of the utility to ultimately |
2 | | manage the grid in a safe, reliable manner. |
3 | | (l) (j) This Section is repealed December 31, 2023.
|
4 | | (Source: P.A. 98-57, eff. 7-5-13.)
|
5 | | (220 ILCS 5/16-107)
|
6 | | Sec. 16-107. Real-time pricing.
|
7 | | (a) Each electric utility shall file, on or before May 1,
|
8 | | 1998, a tariff or tariffs which allow nonresidential retail
|
9 | | customers in the electric utility's service area to elect
|
10 | | real-time pricing beginning October 1, 1998.
|
11 | | (b) Each electric utility shall file, on or before May 1,
|
12 | | 2000, a tariff or tariffs which allow residential retail
|
13 | | customers in the electric utility's service area to elect
|
14 | | real-time pricing beginning October 1, 2000.
|
15 | | (b-5) Each electric utility shall file a tariff or tariffs |
16 | | allowing residential retail customers in the electric |
17 | | utility's service area to elect real-time pricing beginning |
18 | | January 2, 2007. The Commission may, after notice and hearing, |
19 | | approve the tariff or tariffs. A tariff or tariffs approved |
20 | | pursuant to this subsection (b-5) shall, at a minimum, describe |
21 | | (i) the methodology for determining the market price of energy |
22 | | to be reflected in the real-time rate and (ii) the manner in |
23 | | which customers who elect real-time pricing will be provided |
24 | | with ready access to hourly market prices, including, but not |
25 | | limited to, day-ahead hourly energy prices. A customer who |
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1 | | elects real-time pricing under a tariff approved under this |
2 | | subsection (b-5) and thereafter terminates the election shall |
3 | | not return to taking service under the tariff for a period of |
4 | | 12 months following the date on which the customer terminated |
5 | | real-time pricing. However, this limitation shall cease to |
6 | | apply on such date that the provision of electric power and |
7 | | energy is declared competitive under Section 16-113 of this Act |
8 | | for the customer group or groups to which this subsection (b-5) |
9 | | applies. |
10 | | A proceeding under this subsection (b-5) may not exceed 120 |
11 | | days in length.
|
12 | | (b-10) Each electric utility providing real-time pricing |
13 | | pursuant to subsection (b-5) shall install a meter capable of |
14 | | recording hourly interval energy use at the service location of |
15 | | each customer that elects real-time pricing pursuant to this |
16 | | subsection. |
17 | | (b-15) If the Commission issues an order pursuant to |
18 | | subsection (b-5), the affected electric utility shall contract |
19 | | with an entity not affiliated with the electric utility to |
20 | | serve as a program administrator to develop and implement a |
21 | | program to provide consumer outreach, enrollment, and |
22 | | education concerning real-time pricing and to establish and |
23 | | administer an information system and technical and other |
24 | | customer assistance that is necessary to enable customers to |
25 | | manage electricity use. The program administrator: (i) shall be |
26 | | selected and compensated by the electric utility, subject to |
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1 | | Commission approval; (ii) shall have demonstrated technical |
2 | | and managerial competence in the development and |
3 | | administration of demand management programs; and (iii) may |
4 | | develop and implement risk management, energy efficiency, and |
5 | | other services related to energy use management for which the |
6 | | program administrator shall be compensated by participants in |
7 | | the program receiving such services. The electric utility shall |
8 | | provide the program administrator with all information and |
9 | | assistance necessary to perform the program administrator's |
10 | | duties, including, but not limited to, customer, account, and |
11 | | energy use data. The electric utility shall permit the program |
12 | | administrator to include inserts in residential customer bills |
13 | | 2 times per year to assist with customer outreach and |
14 | | enrollment. |
15 | | The program administrator shall submit an annual report to |
16 | | the electric utility no later than April 1 of each year |
17 | | describing the operation and results of the program, including |
18 | | information concerning the number and types of customers using |
19 | | real-time pricing, changes in customers' energy use patterns, |
20 | | an assessment of the value of the program to both participants |
21 | | and non-participants, and recommendations concerning |
22 | | modification of the program and the tariff or tariffs filed |
23 | | under subsection (b-5). This report shall be filed by the |
24 | | electric utility with the Commission within 30 days of receipt |
25 | | and shall be available to the public on the Commission's web |
26 | | site. |
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1 | | (b-20) The Commission shall monitor the performance of |
2 | | programs established pursuant to subsection (b-15) and shall |
3 | | order the termination or modification of a program if it |
4 | | determines that the program is not, after a reasonable period |
5 | | of time for development not to exceed 4 years, resulting in net |
6 | | benefits to the residential customers of the electric utility.
|
7 | | (b-25) An electric utility shall be entitled to recover |
8 | | reasonable costs incurred in complying with this Section, |
9 | | provided that recovery of the costs is fairly apportioned among |
10 | | its residential customers as provided in this subsection |
11 | | (b-25). The electric utility may apportion costs on the |
12 | | residential customers who elect real-time pricing, but may also |
13 | | impose some of the costs of real-time pricing on customers who |
14 | | do not elect real-time pricing.
|
15 | | (c) The electric utility's tariff or tariffs filed
pursuant |
16 | | to this Section shall be subject to Article IX.
|
17 | | (d) This Section does not apply to any electric utility |
18 | | providing service to 100,000 or fewer customers.
|
19 | | (e) Eligible customers shall include, but are not limited |
20 | | to, customers participating in net electricity metering under |
21 | | the terms of Section 16-107.5 of this Act. |
22 | | (Source: P.A. 99-906, eff. 6-1-17 .)
|
23 | | (220 ILCS 5/16-107.5)
|
24 | | Sec. 16-107.5. Net electricity metering. |
25 | | (a) The General Assembly Legislature finds and declares |
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1 | | that a program to provide net electricity
metering, as defined |
2 | | in this Section,
for eligible customers can encourage private |
3 | | investment in renewable energy
resources, stimulate
economic |
4 | | growth, enhance the continued diversification of Illinois' |
5 | | energy
resource mix, and protect
the Illinois environment. The |
6 | | General Assembly further finds and declares that ensuring a |
7 | | smooth, predictable transition from full net metering of the |
8 | | retail electricity rate to the distributed generation rebate |
9 | | described in Section 16-107.6 of this Act is important to |
10 | | achieve these legislative goals. In implementing this |
11 | | transition, the Commission shall ensure that distributed |
12 | | generation customers are fairly compensated for the benefits |
13 | | and services that customer-sited distributed generation |
14 | | provides and that the distributed generation market in Illinois |
15 | | continues to experience stable growth for both small and large |
16 | | customers.
|
17 | | (b) As used in this Section, (i) "community renewable |
18 | | generation project" shall have the meaning set forth in Section |
19 | | 1-10 of the Illinois Power Agency Act; (ii) "eligible customer" |
20 | | means a retail
customer that owns or operates a
solar, wind, or |
21 | | other eligible renewable electrical generating facility with a |
22 | | rated capacity of not more than
2,000 kilowatts that is
located |
23 | | on the customer's premises and is intended primarily to offset |
24 | | the customer's
own electrical requirements; (iii) "electricity |
25 | | provider" means an electric utility or alternative retail |
26 | | electric supplier; (iv) "eligible renewable electrical |
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1 | | generating facility" means a generator that is interconnected |
2 | | under rules adopted by the Commission and is powered by solar |
3 | | electric energy, wind, dedicated crops grown for electricity |
4 | | generation, agricultural residues, untreated and unadulterated |
5 | | wood waste, landscape trimmings, livestock manure, anaerobic |
6 | | digestion of livestock or food processing waste, fuel cells or |
7 | | microturbines powered by renewable fuels, or hydroelectric |
8 | | energy; (v) "net electricity metering" (or "net metering") |
9 | | means the
measurement, during the
billing period applicable to |
10 | | an eligible customer, of the net amount of
electricity supplied |
11 | | by an
electricity provider to the customer's premises or |
12 | | provided to the electricity provider by the customer or |
13 | | subscriber; (vi) "subscriber" shall have the meaning as set |
14 | | forth in Section 1-10 of the Illinois Power Agency Act; and |
15 | | (vii) "subscription" shall have the meaning set forth in |
16 | | Section 1-10 of the Illinois Power Agency Act.
|
17 | | (c) A net metering facility shall be equipped with metering |
18 | | equipment that can measure the flow of electricity in both |
19 | | directions at the same rate. |
20 | | (1) For eligible customers whose electric service has |
21 | | not been declared competitive pursuant to Section 16-113 of |
22 | | this Act as of July 1, 2011 and whose electric delivery |
23 | | service is provided and measured on a kilowatt-hour basis |
24 | | and electric supply service is not provided based on hourly |
25 | | pricing, this shall typically be accomplished through use |
26 | | of a single, bi-directional meter. If the eligible |
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1 | | customer's existing electric revenue meter does not meet |
2 | | this requirement, the electricity provider shall arrange |
3 | | for the local electric utility or a meter service provider |
4 | | to install and maintain a new revenue meter at the |
5 | | electricity provider's expense, which may be the smart |
6 | | meter described by subsection (b) of Section 16-108.5 of |
7 | | this Act. |
8 | | (2) For eligible customers whose electric service has |
9 | | not been declared competitive pursuant to Section 16-113 of |
10 | | this Act as of July 1, 2011 and whose electric delivery |
11 | | service is provided and measured on a kilowatt demand basis |
12 | | and electric supply service is not provided based on hourly |
13 | | pricing, this shall typically be accomplished through use |
14 | | of a dual channel meter capable of measuring the flow of |
15 | | electricity both into and out of the customer's facility at |
16 | | the same rate and ratio. If such customer's existing |
17 | | electric revenue meter does not meet this requirement, then |
18 | | the electricity provider shall arrange for the local |
19 | | electric utility or a meter service provider to install and |
20 | | maintain a new revenue meter at the electricity provider's |
21 | | expense, which may be the smart meter described by |
22 | | subsection (b) of Section 16-108.5 of this Act. |
23 | | (3) For all other eligible customers, until such time |
24 | | as the local electric utility installs a smart meter, as |
25 | | described by subsection (b) of Section 16-108.5 of this |
26 | | Act, the electricity provider may arrange for the local |
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1 | | electric utility or a meter service provider to install and |
2 | | maintain metering equipment capable of measuring the flow |
3 | | of electricity both into and out of the customer's facility |
4 | | at the same rate and ratio, typically through the use of a |
5 | | dual channel meter. If the eligible customer's existing |
6 | | electric revenue meter does not meet this requirement, then |
7 | | the costs of installing such equipment shall be paid for by |
8 | | the customer.
|
9 | | (d) An electricity provider shall
measure and charge or |
10 | | credit for the net
electricity supplied to eligible customers |
11 | | or provided by eligible customers whose electric service has |
12 | | not been declared competitive pursuant to Section 16-113 of |
13 | | this Act as of July 1, 2011 and whose electric delivery service |
14 | | is provided and measured on a kilowatt-hour basis and electric |
15 | | supply service is not provided based on hourly pricing in
the |
16 | | following manner:
|
17 | | (1) If the amount of electricity used by the customer |
18 | | during the billing
period exceeds the
amount of electricity |
19 | | produced by the customer, the electricity provider shall |
20 | | charge the customer for the net electricity supplied to and |
21 | | used
by the customer as provided in subsection (e-5) of |
22 | | this Section.
|
23 | | (2) If the amount of electricity produced by a customer |
24 | | during the billing period exceeds the amount of electricity |
25 | | used by the customer during that billing period, the |
26 | | electricity provider supplying that customer shall apply a |
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1 | | 1:1 kilowatt-hour credit to a subsequent bill for service |
2 | | to the customer for the net electricity supplied to the |
3 | | electricity provider. The electricity provider shall |
4 | | continue to carry over any excess kilowatt-hour credits |
5 | | earned and apply those credits to subsequent billing |
6 | | periods to offset any customer-generator consumption in |
7 | | those billing periods until all credits are used or until |
8 | | the end of the annualized period.
|
9 | | (3) At the end of the year or annualized over the |
10 | | period that service is supplied by means of net metering, |
11 | | or in the event that the retail customer terminates service |
12 | | with the electricity provider prior to the end of the year |
13 | | or the annualized period, any remaining credits in the |
14 | | customer's account shall expire.
|
15 | | (d-5) An electricity provider shall measure and charge or |
16 | | credit for the net electricity
supplied to eligible customers |
17 | | or provided by eligible customers whose electric service has |
18 | | not
been declared competitive pursuant to Section 16-113 of |
19 | | this Act as of July 1, 2011 and whose electric delivery
service |
20 | | is provided and measured on a kilowatt-hour basis and electric |
21 | | supply service is provided
based on hourly pricing in the |
22 | | following manner: |
23 | | (1) If the amount of electricity used by the customer |
24 | | during any hourly period exceeds the amount of electricity |
25 | | produced by the customer, the electricity provider shall |
26 | | charge the customer for the net electricity supplied to and |
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1 | | used by the customer according to the terms of the contract |
2 | | or tariff to which the same customer would be assigned to |
3 | | or be eligible for if the customer was not a net metering |
4 | | customer. |
5 | | (2) If the amount of electricity produced by a customer |
6 | | during any hourly period exceeds the amount of electricity |
7 | | used by the customer during that hourly period, the energy |
8 | | provider shall apply a credit for the net kilowatt-hours |
9 | | produced in such period. The credit shall consist of an |
10 | | energy credit and a delivery service credit. The energy
|
11 | | credit shall be valued at the same price per kilowatt-hour |
12 | | as the electric service provider
would charge for |
13 | | kilowatt-hour energy sales during that same hourly period. |
14 | | The delivery credit shall be equal to the net |
15 | | kilowatt-hours produced in such hourly period times a |
16 | | credit that reflects all kilowatt-hour based charges in the |
17 | | customer's electric service rate, excluding energy |
18 | | charges. |
19 | | (e) An electricity provider shall measure and charge or |
20 | | credit for the net electricity supplied to eligible customers |
21 | | whose electric service has not been declared competitive |
22 | | pursuant to Section 16-113 of this Act as of July 1, 2011 and |
23 | | whose electric delivery service is provided and measured on a |
24 | | kilowatt demand basis and electric supply service is not |
25 | | provided based on hourly pricing in the following manner: |
26 | | (1) If the amount of electricity used by the customer |
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1 | | during the billing period exceeds the amount of electricity |
2 | | produced by the customer, then the electricity provider |
3 | | shall charge the customer for the net electricity supplied |
4 | | to and used by the customer as provided in subsection (e-5) |
5 | | of this Section. The customer shall remain responsible for |
6 | | all taxes, fees, and utility delivery charges that would |
7 | | otherwise be applicable to the net amount of electricity |
8 | | used by the customer. |
9 | | (2) If the amount of electricity produced by a customer |
10 | | during the billing period exceeds the amount of electricity |
11 | | used by the customer during that billing period, then the |
12 | | electricity provider supplying that customer shall apply a |
13 | | 1:1 kilowatt-hour credit that reflects the kilowatt-hour |
14 | | based charges in the customer's electric service rate to a |
15 | | subsequent bill for service to the customer for the net |
16 | | electricity supplied to the electricity provider. The |
17 | | electricity provider shall continue to carry over any |
18 | | excess kilowatt-hour credits earned and apply those |
19 | | credits to subsequent billing periods to offset any |
20 | | customer-generator consumption in those billing periods |
21 | | until all credits are used or until the end of the |
22 | | annualized period. |
23 | | (3) At the end of the year or annualized over the |
24 | | period that service is supplied by means of net metering, |
25 | | or in the event that the retail customer terminates service |
26 | | with the electricity provider prior to the end of the year |
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1 | | or the annualized period, any remaining credits in the |
2 | | customer's account shall expire. |
3 | | (e-5) An electricity provider shall provide electric |
4 | | service to eligible customers who utilize net metering at |
5 | | non-discriminatory rates that are identical, with respect to |
6 | | rate structure, retail rate components, and any monthly |
7 | | charges, to the rates that the customer would be charged if not |
8 | | a net metering customer. An electricity provider shall not |
9 | | charge net metering customers any fee or charge or require |
10 | | additional equipment, insurance, or any other requirements not |
11 | | specifically authorized by interconnection standards |
12 | | authorized by the Commission, unless the fee, charge, or other |
13 | | requirement would apply to other similarly situated customers |
14 | | who are not net metering customers. The customer will remain |
15 | | responsible for all taxes, fees, and utility delivery charges |
16 | | that would otherwise be applicable to the net amount of |
17 | | electricity used by the customer. Subsections (c) through (e) |
18 | | of this Section shall not be construed to prevent an |
19 | | arms-length agreement between an electricity provider and an |
20 | | eligible customer that sets forth different prices, terms, and |
21 | | conditions for the provision of net metering service, |
22 | | including, but not limited to, the provision of the appropriate |
23 | | metering equipment for non-residential customers.
|
24 | | (f) Notwithstanding the requirements of subsections (c) |
25 | | through (e-5) of this Section, an electricity provider must |
26 | | require dual-channel metering for customers operating eligible |
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1 | | renewable electrical generating facilities with a nameplate |
2 | | rating up to 2,000 kilowatts and to whom the provisions of |
3 | | neither subsection (d), (d-5), nor (e) of this Section apply. |
4 | | In such cases, electricity charges and credits shall be |
5 | | determined as follows:
|
6 | | (1) The electricity provider shall assess and the |
7 | | customer remains responsible for all taxes, fees, and |
8 | | utility delivery charges that would otherwise be |
9 | | applicable to the gross amount of kilowatt-hours supplied |
10 | | to the eligible customer by the electricity provider. |
11 | | (2) Each month that service is supplied by means of |
12 | | dual-channel metering, the electricity provider shall |
13 | | compensate the eligible customer for any excess |
14 | | kilowatt-hour credits at the electricity provider's |
15 | | avoided cost of electricity supply over the monthly period |
16 | | or as otherwise specified by the terms of a power-purchase |
17 | | agreement negotiated between the customer and electricity |
18 | | provider. |
19 | | (3) For all eligible net metering customers taking |
20 | | service from an electricity provider under contracts or |
21 | | tariffs employing hourly or time of use rates, any monthly |
22 | | consumption of electricity shall be calculated according |
23 | | to the terms of the contract or tariff to which the same |
24 | | customer would be assigned to or be eligible for if the |
25 | | customer was not a net metering customer. When those same |
26 | | customer-generators are net generators during any discrete |
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1 | | hourly or time of use period, the net kilowatt-hours |
2 | | produced shall be valued at the same price per |
3 | | kilowatt-hour as the electric service provider would |
4 | | charge for retail kilowatt-hour sales during that same time |
5 | | of use period.
|
6 | | (g) For purposes of federal and State laws providing |
7 | | renewable energy credits or greenhouse gas credits, the |
8 | | eligible customer shall be treated as owning and having title |
9 | | to the renewable energy attributes, renewable energy credits, |
10 | | and greenhouse gas emission credits related to any electricity |
11 | | produced by the qualified generating unit. The electricity |
12 | | provider may not condition participation in a net metering |
13 | | program on the signing over of a customer's renewable energy |
14 | | credits; provided, however, this subsection (g) shall not be |
15 | | construed to prevent an arms-length agreement between an |
16 | | electricity provider and an eligible customer that sets forth |
17 | | the ownership or title of the credits.
|
18 | | (h) Within 120 days after the effective date of this
|
19 | | amendatory Act of the 95th General Assembly, the Commission |
20 | | shall establish standards for net metering and, if the |
21 | | Commission has not already acted on its own initiative, |
22 | | standards for the interconnection of eligible renewable |
23 | | generating equipment to the utility system. The |
24 | | interconnection standards shall address any procedural |
25 | | barriers, delays, and administrative costs associated with the |
26 | | interconnection of customer-generation while ensuring the |
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1 | | safety and reliability of the units and the electric utility |
2 | | system. The Commission shall consider the Institute of |
3 | | Electrical and Electronics Engineers (IEEE) Standard 1547 and |
4 | | the issues of (i) reasonable and fair fees and costs, (ii) |
5 | | clear timelines for major milestones in the interconnection |
6 | | process, (iii) nondiscriminatory terms of agreement, and (iv) |
7 | | any best practices for interconnection of distributed |
8 | | generation.
|
9 | | (i) All electricity providers shall begin to offer net |
10 | | metering
no later than April 1,
2008.
|
11 | | (j) An electricity provider shall provide net metering to |
12 | | eligible
customers until the load of its net metering customers |
13 | | equals 5% of
the total peak demand supplied by
that electricity |
14 | | provider during the
previous year. After such time as the load |
15 | | of the electricity provider's net metering customers equals 5% |
16 | | of the total peak demand supplied by that electricity provider |
17 | | during the previous year and after the effective date of the |
18 | | distributed generation rebate tariffs prescribed by subsection |
19 | | (e) of Section 16-107.6 of this Act , eligible customers that |
20 | | begin taking net metering shall only be eligible for netting of |
21 | | energy.
|
22 | | (k) Each electricity provider shall maintain records and |
23 | | report annually to the Commission the total number of net |
24 | | metering customers served by the provider, as well as the type, |
25 | | capacity, and energy sources of the generating systems used by |
26 | | the net metering customers. Nothing in this Section shall limit |
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1 | | the ability of an electricity provider to request the redaction |
2 | | of information deemed by the Commission to be confidential |
3 | | business information. |
4 | | (l)(1) Notwithstanding the definition of "eligible |
5 | | customer" in item (ii) of subsection (b) of this Section, |
6 | | each electricity provider shall allow net metering as set |
7 | | forth in this subsection (l) and for the following |
8 | | projects:
|
9 | | (A) properties owned or leased by multiple |
10 | | customers that contribute to the operation of an |
11 | | eligible renewable electrical generating facility |
12 | | through an ownership or leasehold interest of at least |
13 | | 200 watts in such facility, such as a community-owned |
14 | | wind project, a community-owned biomass project, a |
15 | | community-owned solar project, or a community methane |
16 | | digester processing livestock waste from multiple |
17 | | sources, provided that the facility is also located |
18 | | within the utility's service territory;
|
19 | | (B) individual units, apartments, or properties |
20 | | located in a single building that are owned or leased |
21 | | by multiple customers and collectively served by a |
22 | | common eligible renewable electrical generating |
23 | | facility, such as an office or apartment building, a |
24 | | shopping center or strip mall served by photovoltaic |
25 | | panels on the roof; and
|
26 | | (C) subscriptions to community renewable |
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1 | | generation projects. |
2 | | In addition, the nameplate capacity of the eligible |
3 | | renewable electric generating facility that serves the |
4 | | demand of the properties, units, or apartments identified |
5 | | in paragraphs (1) and (2) of this subsection (l) shall not |
6 | | exceed 2,000 kilowatts in nameplate capacity in total.
Any |
7 | | eligible renewable electrical generating facility or |
8 | | community renewable generation project that is powered by |
9 | | photovoltaic electric energy and installed after the |
10 | | effective date of this amendatory Act of the 99th General |
11 | | Assembly must be installed by a qualified person in |
12 | | compliance with the requirements of Section 16-128A of the |
13 | | Public Utilities Act and any rules or regulations adopted |
14 | | thereunder. |
15 | | (2) Notwithstanding anything to the contrary, an |
16 | | electricity provider shall provide credits for the |
17 | | electricity produced by the projects described in |
18 | | paragraph (1) of this subsection (l). The electricity |
19 | | provider shall provide credits at the subscriber's energy |
20 | | supply rate on the subscriber's monthly bill equal to the |
21 | | subscriber's share of the production of electricity from |
22 | | the project, as determined by paragraph (3) of this |
23 | | subsection (l). |
24 | | (3) For the purposes of facilitating net metering, the |
25 | | owner or operator of the eligible renewable electrical |
26 | | generating facility or community renewable generation |
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1 | | project shall be responsible for determining the amount of |
2 | | the credit that each customer or subscriber participating |
3 | | in a project under this subsection (l) is to receive in the |
4 | | following manner:
|
5 | | (A) The owner or operator shall, on a monthly |
6 | | basis, provide to the electric utility the |
7 | | kilowatthours of generation attributable to each of |
8 | | the utility's retail customers and subscribers |
9 | | participating in projects under this subsection (l) in |
10 | | accordance with the customer's or subscriber's share |
11 | | of the eligible renewable electric generating |
12 | | facility's or community renewable generation project's |
13 | | output of power and energy for such month. The owner or |
14 | | operator shall electronically transmit such |
15 | | calculations and associated documentation to the |
16 | | electric utility, in a format or method set forth in |
17 | | the applicable tariff, on a monthly basis so that the |
18 | | electric utility can reflect the monetary credits on |
19 | | customers' and subscribers' electric utility bills. |
20 | | The electric utility shall be permitted to revise its |
21 | | tariffs to implement the provisions of this amendatory |
22 | | Act of the 99th General Assembly. The owner or operator |
23 | | shall separately provide the electric utility with the |
24 | | documentation detailing the calculations supporting |
25 | | the credit in the manner set forth in the applicable |
26 | | tariff. |
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1 | | (B) For those participating customers and |
2 | | subscribers who receive their energy supply from an |
3 | | alternative retail electric supplier, the electric |
4 | | utility shall remit to the applicable alternative |
5 | | retail electric supplier the information provided |
6 | | under subparagraph (A) of this paragraph (3) for such |
7 | | customers and subscribers in a manner set forth in such |
8 | | alternative retail electric supplier's net metering |
9 | | program, or as otherwise agreed between the utility and |
10 | | the alternative retail electric supplier. The |
11 | | alternative retail electric supplier shall then submit |
12 | | to the utility the amount of the charges for power and |
13 | | energy to be applied to such customers and subscribers, |
14 | | including the amount of the credit associated with net |
15 | | metering. |
16 | | (C) A participating customer or subscriber may |
17 | | provide authorization as required by applicable law |
18 | | that directs the electric utility to submit |
19 | | information to the owner or operator of the eligible |
20 | | renewable electrical generating facility or community |
21 | | renewable generation project to which the customer or |
22 | | subscriber has an ownership or leasehold interest or a |
23 | | subscription. Such information shall be limited to the |
24 | | components of the net metering credit calculated under |
25 | | this subsection (l), including the bill credit rate, |
26 | | total kilowatthours, and total monetary credit value |
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1 | | applied to the customer's or subscriber's bill for the |
2 | | monthly billing period. |
3 | | (l-5) Within 90 days after the effective date of this |
4 | | amendatory Act of the 99th General Assembly, each electric |
5 | | utility subject to this Section shall file a tariff to |
6 | | implement the provisions of subsection (l) of this Section, |
7 | | which shall, consistent with the provisions of subsection (l), |
8 | | describe the terms and conditions under which owners or |
9 | | operators of qualifying properties, units, or apartments may |
10 | | participate in net metering. The Commission shall approve, or |
11 | | approve with modification, the tariff within 120 days after the |
12 | | effective date of this amendatory Act of the 99th General |
13 | | Assembly. |
14 | | (m) Nothing in this Section shall affect the right of an |
15 | | electricity provider to continue to provide, or the right of a |
16 | | retail customer to continue to receive service pursuant to a |
17 | | contract for electric service between the electricity provider |
18 | | and the retail customer in accordance with the prices, terms, |
19 | | and conditions provided for in that contract. Either the |
20 | | electricity provider or the customer may require compliance |
21 | | with the prices, terms, and conditions of the contract.
|
22 | | (n) At such time, if any, that the load of the electricity |
23 | | provider's net metering customers equals 5% of the total peak |
24 | | demand supplied by that electricity provider during the |
25 | | previous year, as specified in subsection (j) of this Section, |
26 | | the net metering services described in subsections (d), (d-5), |
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1 | | (e), (e-5), and (f) of this Section shall no longer be offered, |
2 | | except as to those retail customers that are receiving net |
3 | | metering service under these subsections at the time the net |
4 | | metering services under those subsections are no longer |
5 | | offered. Those retail customers that begin taking net metering |
6 | | service after the date that net metering services are no longer |
7 | | offered under such subsections shall be subject to the |
8 | | provisions set forth in the following paragraphs (1) through |
9 | | (3) of this subsection (n): |
10 | | (1) An electricity provider shall charge or credit for |
11 | | the net electricity supplied to eligible customers or |
12 | | provided by eligible customers whose electric supply |
13 | | service is not provided based on hourly pricing in the |
14 | | following manner: |
15 | | (A) If the amount of electricity used by the |
16 | | customer during the billing period exceeds the amount |
17 | | of electricity produced by the customer, then the |
18 | | electricity provider shall charge the customer for the |
19 | | net kilowatt-hour based electricity charges reflected |
20 | | in the customer's electric service rate supplied to and |
21 | | used by the customer as provided in paragraph (3) of |
22 | | this subsection (n). |
23 | | (B) If the amount of electricity produced by a |
24 | | customer during the billing period exceeds the amount |
25 | | of electricity used by the customer during that billing |
26 | | period, then the electricity provider supplying that |
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1 | | customer shall apply a 1:1 kilowatt-hour energy credit |
2 | | that reflects the kilowatt-hour based energy charges |
3 | | in the customer's electric service rate to a subsequent |
4 | | bill for service to the customer for the net |
5 | | electricity supplied to the electricity provider. The |
6 | | electricity provider shall continue to carry over any |
7 | | excess kilowatt-hour energy credits earned and apply |
8 | | those credits to subsequent billing periods to offset |
9 | | any customer-generator consumption in those billing |
10 | | periods until all credits are used or until the end of |
11 | | the annualized period. |
12 | | (C) At the end of the year or annualized over the |
13 | | period that service is supplied by means of net |
14 | | metering, or in the event that the retail customer |
15 | | terminates service with the electricity provider prior |
16 | | to the end of the year or the annualized period, any |
17 | | remaining credits in the customer's account shall |
18 | | expire. |
19 | | (2) An electricity provider shall charge or credit for |
20 | | the net electricity supplied to eligible customers or |
21 | | provided by eligible customers whose electric supply |
22 | | service is provided based on hourly pricing in the |
23 | | following manner: |
24 | | (A) If the amount of electricity used by the |
25 | | customer during any hourly period exceeds the amount of |
26 | | electricity produced by the customer, then the |
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1 | | electricity provider shall charge the customer for the |
2 | | net electricity supplied to and used by the customer as |
3 | | provided in paragraph (3) of this subsection (n). |
4 | | (B) If the amount of electricity produced by a |
5 | | customer during any hourly period exceeds the amount of |
6 | | electricity used by the customer during that hourly |
7 | | period, the energy provider shall calculate an energy |
8 | | credit for the net kilowatt-hours produced in such |
9 | | period. The value of the energy credit shall be |
10 | | calculated using the same price per kilowatt-hour as |
11 | | the electric service provider would charge for |
12 | | kilowatt-hour energy sales during that same hourly |
13 | | period. |
14 | | (3) An electricity provider shall provide electric |
15 | | service to eligible customers who utilize net metering at |
16 | | non-discriminatory rates that are identical, with respect |
17 | | to rate structure, retail rate components, and any monthly |
18 | | charges, to the rates that the customer would be charged if |
19 | | not a net metering customer. An electricity provider shall |
20 | | charge the customer for the net electricity supplied to and |
21 | | used by the customer according to the terms of the contract |
22 | | or tariff to which the same customer would be assigned or |
23 | | be eligible for if the customer was not a net metering |
24 | | customer. An electricity provider shall not charge net |
25 | | metering customers any fee or charge or require additional |
26 | | equipment, insurance, or any other requirements not |
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1 | | specifically authorized by interconnection standards |
2 | | authorized by the Commission, unless the fee, charge, or |
3 | | other requirement would apply to other similarly situated |
4 | | customers who are not net metering customers. The charge or |
5 | | credit that the customer receives for net electricity shall |
6 | | be at a rate equal to the customer's energy supply rate. |
7 | | The customer remains responsible for the gross amount of |
8 | | delivery services charges, supply-related charges that are |
9 | | kilowatt based, and all taxes and fees related to such |
10 | | charges. The customer also remains responsible for all |
11 | | taxes and fees that would otherwise be applicable to the |
12 | | net amount of electricity used by the customer. Paragraphs |
13 | | (1) and (2) of this subsection (n) shall not be construed |
14 | | to prevent an arms-length agreement between an electricity |
15 | | provider and an eligible customer that sets forth different |
16 | | prices, terms, and conditions for the provision of net |
17 | | metering service, including, but not limited to, the |
18 | | provision of the appropriate metering equipment for |
19 | | non-residential customers. Nothing in this paragraph (3) |
20 | | shall be interpreted to mandate that a utility that is only |
21 | | required to provide delivery services to a given customer |
22 | | must also sell electricity to such customer.
|
23 | | (Source: P.A. 99-906, eff. 6-1-17 .) |
24 | | (220 ILCS 5/16-107.6) |
25 | | Sec. 16-107.6. Distributed generation rebate. |
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1 | | (a) In this Section: |
2 | | "Smart inverter" means a device that converts direct |
3 | | current
into alternating current and can autonomously |
4 | | contribute to grid support during excursions from normal |
5 | | operating voltage and frequency conditions by providing each of |
6 | | the following: dynamic reactive and real power support, voltage |
7 | | and frequency ride-through, ramp rate controls, communication |
8 | | systems with ability to accept external commands, and other |
9 | | functions from the electric utility. |
10 | | "Distribution system reliability event" means when, for |
11 | | standard service voltage, voltage variations are measured at |
12 | | any customer's point of delivery above a maximum of 127 volts |
13 | | or below a minimum of 113 volts for periods longer than 2 |
14 | | minutes in each instance. |
15 | | "Subscriber" has the meaning set forth in Section 1-10 of |
16 | | the Illinois Power Agency Act. |
17 | | "Subscription" has the meaning set forth in Section 1-10 of |
18 | | the Illinois Power Agency Act. |
19 | | "Threshold date" means the date on which the load of an |
20 | | electricity provider's net metering customers equals 5% of the |
21 | | total peak demand supplied by that electricity provider during |
22 | | the previous year, as specified under subsection (j) of Section |
23 | | 16-107.5 of this Act. |
24 | | (b) An electric utility that serves more than 200,000 |
25 | | customers in the State shall file a petition with the |
26 | | Commission requesting approval of the utility's tariff to |
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1 | | provide a rebate to a retail customer who owns or operates |
2 | | distributed generation that meets the following criteria: |
3 | | (1) has a nameplate generating capacity no greater than |
4 | | 2,000 kilowatts and is primarily used to offset that |
5 | | customer's electricity load; |
6 | | (2) is located on the customer's premises, for the |
7 | | customer's own use, and not for commercial use or sales, |
8 | | including, but not limited to, wholesale sales of electric |
9 | | power and energy; |
10 | | (3) is located in the electric utility's service |
11 | | territory; and |
12 | | (4) is interconnected under rules adopted by the |
13 | | Commission by means of the inverter or smart inverter |
14 | | required by this Section, as applicable. |
15 | | For purposes of this Section, "distributed generation" |
16 | | shall satisfy the definition of distributed renewable energy |
17 | | generation device set forth in Section 1-10 of the Illinois |
18 | | Power Agency Act to the extent such definition is consistent |
19 | | with the requirements of this Section. |
20 | | In addition, any new photovoltaic distributed generation |
21 | | that is installed after the effective date of this amendatory |
22 | | Act of the 99th General Assembly must be installed by a |
23 | | qualified person, as defined by subsection (i) of Section 1-56 |
24 | | of the Illinois Power Agency Act. |
25 | | The tariff shall provide that the utility shall be |
26 | | permitted to operate and control the smart inverter associated |
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1 | | with the distributed generation that is the subject of the |
2 | | rebate for the purpose of preserving reliability during |
3 | | distribution system reliability events and shall address the |
4 | | terms and conditions of the operation and the compensation |
5 | | associated with the operation. Nothing in this Section shall |
6 | | negate or supersede Institute of Electrical and Electronics |
7 | | Engineers interconnection requirements or standards or other |
8 | | similar standards or requirements. The tariff shall also |
9 | | provide for additional uses of the smart inverter that shall be |
10 | | separately compensated and which may include, but are not |
11 | | limited to, voltage and VAR support, regulation, and other grid |
12 | | services. As part of the proceeding described in subsection (e) |
13 | | of this Section, the Commission shall review and determine |
14 | | whether smart inverters can provide any additional uses or |
15 | | services. If the Commission determines that an additional use |
16 | | or service would be beneficial, the Commission shall determine |
17 | | the terms and conditions of the operation and how the use or |
18 | | service should be separately compensated. |
19 | | (c) The proposed tariff authorized by subsection (b) of |
20 | | this Section shall include the following participation terms |
21 | | and formulae to calculate the value of the rebates to be |
22 | | applied under this Section for distributed generation that |
23 | | satisfies the criteria set forth in subsection (b) of this |
24 | | Section: |
25 | | (1) Until the utility files its tariff or tariffs to |
26 | | place into effect the rebate values established by the |
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1 | | Commission under subsection (e) of this Section, |
2 | | non-residential customers that are taking service under a |
3 | | net metering program offered by an electricity provider |
4 | | under the terms of Section 16-107.5 of this Act may apply |
5 | | for a rebate as provided for in this Section. The value of |
6 | | the rebate shall be $250 per kilowatt of nameplate |
7 | | generating capacity, measured as nominal DC power output, |
8 | | of a non-residential customer's distributed generation. |
9 | | (2) After the utility's tariff or tariffs setting the |
10 | | new rebate values established under subsection (d) of this |
11 | | Section take effect, retail customers may, as applicable, |
12 | | make the following elections: |
13 | | (A) Residential customers that are taking service |
14 | | under a net metering program offered by an electricity |
15 | | provider under the terms of Section 16-107.5 of this |
16 | | Act on the threshold date may elect to either continue |
17 | | to take such service under the terms of such program as |
18 | | in effect on such threshold date for the useful life of |
19 | | the customer's eligible renewable electric generating |
20 | | facility as defined in such Section, or file an |
21 | | application to receive a rebate under the terms of this |
22 | | Section, provided that such application must be |
23 | | submitted within 6 months after the effective date of |
24 | | the tariff approved under subsection (d) of this |
25 | | Section. The value of the rebate shall be the amount |
26 | | established by the Commission and reflected in the |
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1 | | utility's tariff pursuant to subsection (e) of this |
2 | | Section. |
3 | | (B) Non-residential customers that are taking |
4 | | service under a net metering program offered by an |
5 | | electricity provider under the terms of Section |
6 | | 16-107.5 of this Act on the threshold date may apply |
7 | | for a rebate as provided for in this Section. The value |
8 | | of the rebate shall be the amount established by the |
9 | | Commission and reflected in the utility's tariff |
10 | | pursuant to subsection (e) of this Section. |
11 | | (3) Upon approval of a rebate application submitted |
12 | | under this subsection (c), the retail customer shall no |
13 | | longer be entitled to receive any delivery service credits |
14 | | for the excess electricity generated by its facility and |
15 | | shall be subject to the provisions of subsection (n) of |
16 | | Section 16-107.5 of this Act. |
17 | | (4) To be eligible for a rebate described in this |
18 | | subsection (c), customers who begin taking service after |
19 | | the effective date of this amendatory Act of the 99th |
20 | | General Assembly under a net metering program offered by an |
21 | | electricity provider under the terms of Section 16-107.5 of |
22 | | this Act must have a smart inverter associated with the |
23 | | customer's distributed generation. |
24 | | (d) The Commission shall review the proposed tariff |
25 | | submitted under subsections (b) and (c) of this Section and may |
26 | | make changes to the tariff that are consistent with this |
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1 | | Section and with the Commission's authority under Article IX of |
2 | | this Act, subject to notice and hearing. Following notice and |
3 | | hearing, the Commission shall issue an order approving, or |
4 | | approving with modification, such tariff no later than 240 days |
5 | | after the utility files its tariff. |
6 | | (e) When the total generating capacity of the electricity |
7 | | provider's net metering customers is equal to 3%, the |
8 | | Commission shall open an investigation into an annual process |
9 | | and formula for calculating the value of rebates for the retail |
10 | | customers described in subsections (b) and (f) of this Section |
11 | | that submit rebate applications after the threshold date for an |
12 | | electric utility that elected to file a tariff pursuant to this |
13 | | Section. The investigation shall include diverse sets of |
14 | | stakeholders, calculations for valuing distributed energy |
15 | | resource benefits to the grid based on best practices, and |
16 | | assessments of present and future technological capabilities |
17 | | of distributed energy resources. The value of such rebates |
18 | | shall reflect the value of the distributed generation to the |
19 | | distribution system at the location at which it is |
20 | | interconnected, taking into account the geographic, |
21 | | time-based, and performance-based benefits, as well as |
22 | | technological capabilities and present and future grid needs. |
23 | | The approved tariff shall provide for volumetric-based cost |
24 | | recovery. The Commission shall assign a higher value for |
25 | | rebates for distributed generation co-located with |
26 | | appropriately-sized energy storage systems that reflect the |
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1 | | additional values that energy storage can provide to the energy |
2 | | system. The Commission shall assign an additional value for |
3 | | distributed generation that is co-located or in close proximity |
4 | | to electric vehicle charging infrastructure that is part of a |
5 | | managed charging or time-of-use program, or other beneficial |
6 | | electrification program, as described in Section 16-107.8 of |
7 | | this Act, reflecting the value of the additional benefits |
8 | | created by locating the project near and supporting the |
9 | | adoption of electric vehicle infrastructure that is helping |
10 | | reduce pollution from the transportation sector.
No later than |
11 | | 10 days after the Commission enters its final order under this |
12 | | subsection (e), the utility shall file its tariff or tariffs in |
13 | | compliance with the order, and the Commission shall approve, or |
14 | | approve with modification, the tariff or tariffs within 45 days |
15 | | after the utility's filing. For those rebate applications filed |
16 | | after the threshold date but before the utility's tariff or |
17 | | tariffs filed pursuant to this subsection (e) take effect, the |
18 | | value of the rebate shall remain at the value established in |
19 | | subsection (c) of this Section until the tariff is approved. As |
20 | | part of the annual process, the Commission shall ensure that |
21 | | the distributed generation rebate results in stable growth for |
22 | | both small and large distributed generation customers in |
23 | | Illinois as provided in subsection (j) of Section 16-107.5 of |
24 | | this Act, with particular attention to impacts for residential |
25 | | customers. |
26 | | (f) Notwithstanding any provision of this Act to the |
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1 | | contrary, the owner, developer, or subscriber of a generation |
2 | | facility that is part of a net metering program provided under |
3 | | subsection (l) of Section 16-107.5 shall also be eligible to |
4 | | apply for the rebate described in this Section. A subscriber to |
5 | | the generation facility may apply for a rebate in the amount of |
6 | | the subscriber's subscription only if the owner, developer, or |
7 | | previous subscriber to the same panel or panels has not already |
8 | | submitted an application, and, regardless of whether the |
9 | | subscriber is a residential or non-residential customer, may be |
10 | | allowed the amount identified in paragraph (1) of subsection |
11 | | (c) or in subsection (e) of this Section applicable to such |
12 | | customer on the date that the application is submitted. An |
13 | | application for a rebate for a portion of a project described |
14 | | in this subsection (f) may be submitted at or after the time |
15 | | that a related request for net metering is made. |
16 | | (g) No later than 60 days after the utility receives an |
17 | | application for a rebate under its tariff approved under |
18 | | subsection (d) or (e) of this Section, the utility shall issue |
19 | | a rebate to the applicant under the terms of the tariff. In the |
20 | | event the application is incomplete or the utility is otherwise |
21 | | unable to calculate the payment based on the information |
22 | | provided by the owner, the utility shall issue the payment no |
23 | | later than 60 days after the application is complete or all |
24 | | requested information is received. |
25 | | (h) An electric utility shall recover from its retail |
26 | | customers all of the costs of the rebates made under a tariff |
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1 | | or tariffs placed into effect under this Section, including, |
2 | | but not limited to, the value of the rebates and all costs |
3 | | incurred by the utility to comply with and implement this |
4 | | Section, consistent with the following provisions: |
5 | | (1) The utility shall defer the full amount of its |
6 | | costs incurred under this Section as a regulatory asset. |
7 | | The total costs deferred as a regulatory asset shall be |
8 | | amortized over a 15-year period. The unamortized balance |
9 | | shall be recognized as of December 31 for a given year. The |
10 | | utility shall also earn a return on the total of the |
11 | | unamortized balance of the regulatory assets, less any |
12 | | deferred taxes related to the unamortized balance, at an |
13 | | annual rate equal to the utility's weighted average cost of |
14 | | capital that includes, based on a year-end capital |
15 | | structure, the utility's actual cost of debt for the |
16 | | applicable calendar year and a cost of equity, which shall |
17 | | be calculated as the sum of (i) the average for the |
18 | | applicable calendar year of the monthly average yields of |
19 | | 30-year U.S. Treasury bonds published by the Board of |
20 | | Governors of the Federal Reserve System in its weekly H.15 |
21 | | Statistical Release or successor publication; and (ii) 580 |
22 | | basis points, including a revenue conversion factor |
23 | | calculated to recover or refund all additional income taxes |
24 | | that may be payable or receivable as a result of that |
25 | | return. |
26 | | When an electric utility creates a regulatory asset |
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1 | | under the provisions of this Section, the costs are |
2 | | recovered over a period during which customers also receive |
3 | | a benefit, which is in the public interest. Accordingly, it |
4 | | is the intent of the General Assembly that an electric |
5 | | utility that elects to create a regulatory asset under the |
6 | | provisions of this Section shall recover all of the |
7 | | associated costs, including, but not limited to, its cost |
8 | | of capital as set forth in this Section. After the |
9 | | Commission has approved the prudence and reasonableness of |
10 | | the costs that comprise the regulatory asset, the electric |
11 | | utility shall be permitted to recover all such costs, and |
12 | | the value and recoverability through rates of the |
13 | | associated regulatory asset shall not be limited, altered, |
14 | | impaired, or reduced. To enable the financing of the |
15 | | incremental capital expenditures, including regulatory |
16 | | assets, for electric utilities that serve less than |
17 | | 3,000,000 retail customers but more than 500,000 retail |
18 | | customers in the State, the utility's actual year-end |
19 | | capital structure that includes a common equity ratio, |
20 | | excluding goodwill, of up to and including 50% of the total |
21 | | capital structure shall be deemed reasonable and used to |
22 | | set rates. |
23 | | (2) The utility, at its election, may recover all of |
24 | | the costs it incurs under this Section as part of a filing |
25 | | for a general increase in rates under Article IX of this |
26 | | Act, as part of an annual filing to update a |
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1 | | performance-based formula rate under subsection (d) of |
2 | | Section 16-108.5 of this Act, or through an automatic |
3 | | adjustment clause tariff, provided that nothing in this |
4 | | paragraph (2) permits the double recovery of such costs |
5 | | from customers. If the utility elects to recover the costs |
6 | | it incurs under this Section through an automatic |
7 | | adjustment clause tariff, the utility may file its proposed |
8 | | tariff together with the tariff it files under subsection |
9 | | (b) of this Section or at a later time. The proposed tariff |
10 | | shall provide for an annual reconciliation, less any |
11 | | deferred taxes related to the reconciliation, with |
12 | | interest at an annual rate of return equal to the utility's |
13 | | weighted average cost of capital as calculated under |
14 | | paragraph (1) of this subsection (h), including a revenue |
15 | | conversion factor calculated to recover or refund all |
16 | | additional income taxes that may be payable or receivable |
17 | | as a result of that return, of the revenue requirement |
18 | | reflected in rates for each calendar year, beginning with |
19 | | the calendar year in which the utility files its automatic |
20 | | adjustment clause tariff under this subsection (h), with |
21 | | what the revenue requirement would have been had the actual |
22 | | cost information for the applicable calendar year been |
23 | | available at the filing date. The Commission shall review |
24 | | the proposed tariff and may make changes to the tariff that |
25 | | are consistent with this Section and with the Commission's |
26 | | authority under Article IX of this Act, subject to notice |
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1 | | and hearing. Following notice and hearing, the Commission |
2 | | shall issue an order approving, or approving with |
3 | | modification, such tariff no later than 240 days after the |
4 | | utility files its tariff. |
5 | | (i) No later than 90 days after the Commission enters an |
6 | | order, or order on rehearing, whichever is later, approving an |
7 | | electric utility's proposed tariff under subsection (d) of this |
8 | | Section, the electric utility shall provide notice of the |
9 | | availability of rebates under this Section. Subsequent to the |
10 | | utility's notice, any entity that offers in the State, for sale |
11 | | or lease, distributed generation and estimates the dollar |
12 | | saving attributable to such distributed generation shall |
13 | | provide estimates based on both delivery service credits and |
14 | | the rebates available under this Section.
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15 | | (Source: P.A. 99-906, eff. 6-1-17 .) |
16 | | (220 ILCS 5/16-107.7 new) |
17 | | Sec. 16-107.7. Residential time-of-use pricing. |
18 | | (a) The General Assembly finds and declares that a time of |
19 | | use pricing plan can reduce costs to the grid, create jobs, |
20 | | lower energy costs for customers, and help Illinois achieve its |
21 | | energy policy goals by improving load shape, encouraging energy |
22 | | conservation, and shifting usage away from periods where fossil |
23 | | fuels are used to meet peak demand. Further, by providing to |
24 | | consumers information that ties the cost of service to the |
25 | | timing of energy use, time-of-use rates give customers the |
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1 | | opportunity to reduce their energy bills by using electricity |
2 | | when it is less costly. Time-of-use rates can help allocate |
3 | | electricity system costs more accurately and thus equitably to |
4 | | those who cause costs. Such rates can also reduce the need for |
5 | | ramping resources and, therefore, increase the grid's ability |
6 | | to integrate greater quantities of variable renewable energy |
7 | | and distributed energy resources. |
8 | | (b) An electric utility that has a tariff in effect under |
9 | | Section 16-108.5 as of the effective date of this amendatory |
10 | | Act of the 101st General Assembly shall also offer a |
11 | | market-based, time-of-use rate for eligible retail customers |
12 | | that choose to take power and energy supply service from the |
13 | | utility. The utility shall file its time-of-use rate tariff no |
14 | | later than 120 days after the effective date of this amendatory |
15 | | Act of the 101st General Assembly. The utility shall implement |
16 | | the requirements of this paragraph by filing a tariff with the |
17 | | Commission, which shall be subject to the following provisions: |
18 | | (1) The tariff shall include 3 time blocks: a peak time |
19 | | block defined as 3 p.m. to 7 p.m. on non-holiday weekdays, |
20 | | an off-peak time block defined as 10 a.m. to 3 p.m. and 7 |
21 | | p.m. to 10 p.m. on non-holiday weekdays, and a |
22 | | super-off-peak time block defined as all other hours. |
23 | | (2) The tariff shall create price ratios between the |
24 | | blocks as follows: the super-off-peak time block price |
25 | | shall be no less than zero but no greater than one-half of |
26 | | the price of the off-peak time block price, and the |
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1 | | off-peak time block price shall be no greater than one-half |
2 | | of the price of the peak time block price. |
3 | | (3) Notwithstanding the requirements of Section |
4 | | 16-103.3 of this Act, the time-of-use rate shall include |
5 | | the costs of electric capacity, costs of transmission |
6 | | services, and charges for network integration transmission |
7 | | service, transmission enhancement, and locational |
8 | | reliability, as these terms are defined in the PJM |
9 | | Interconnection Open Access Transmission Tariff on January |
10 | | 1, 2019, within the prices for each time block and seasonal |
11 | | block in which the associated costs generally are incurred. |
12 | | If the Open Access Transmission Tariff subsequently |
13 | | renames those terms, the services reflected under those |
14 | | terms shall continue to be included in the time-of-use rate |
15 | | described in this paragraph (2). |
16 | | (4) Adjustments to the charges set by the tariff may be |
17 | | made on a semi-annual basis, as follows: each May and |
18 | | November, the utility shall submit to the Commission, |
19 | | through an informational filing, its updated charges, and |
20 | | such charges shall take effect beginning with the June |
21 | | monthly billing period and December monthly billing |
22 | | period, respectively. |
23 | | (5) The tariff shall include a purchased energy |
24 | | adjustment to fully recover the supply costs for the |
25 | | customers taking service under this tariff. |
26 | | "Eligible customers" includes, but is not limited to, |
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1 | | customers participating in net electricity metering under the |
2 | | terms of Section 16-107.5 of this Act. |
3 | | (c) The Commission shall, after notice and hearing, approve |
4 | | the tariff or tariffs with modifications the Commission finds |
5 | | necessary to improve the program design, customer |
6 | | participation in the program, or coordination with existing |
7 | | utility pricing programs, energy efficiency programs, demand |
8 | | response programs, and any other programs supporting Illinois |
9 | | energy policy goals and the integration of distributed energy |
10 | | resources. A proceeding under this subsection may not exceed |
11 | | 120 days in length. |
12 | | (d) If the Commission issues an order pursuant to this |
13 | | subsection, the affected electric utility shall contract with |
14 | | an entity not affiliated with the electric utility to serve as |
15 | | a program administrator to develop and implement a program to |
16 | | provide consumer outreach, enrollment, and education |
17 | | concerning time-of-use pricing and to establish and administer |
18 | | an information system and technical and other customer |
19 | | assistance that is necessary to enable customers to manage |
20 | | electricity use. The program administrator: (i) shall be |
21 | | selected and compensated by the electric utility, subject to |
22 | | Commission approval; (ii) shall have demonstrated technical |
23 | | and managerial competence in the development and |
24 | | administration of demand management programs; and (iii) may |
25 | | develop and implement risk management, energy efficiency, and |
26 | | other services related to energy use management for which the |
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1 | | program administrator shall be compensated by participants in |
2 | | the program receiving such services. The electric utility shall |
3 | | provide the program administrator with all information and |
4 | | assistance necessary to perform the program administrator's |
5 | | duties, including, but not limited to, customer, account, and |
6 | | energy use data. The electric utility shall permit the program |
7 | | administrator to include inserts in residential customer bills |
8 | | 2 times per year to assist with customer outreach and |
9 | | enrollment. |
10 | | The program administrator shall submit an annual report to |
11 | | the electric utility no later than April 1 of each year |
12 | | describing the operation and results of the program, including |
13 | | information concerning the number and types of customers using |
14 | | the program, changes in customers' energy use patterns, an |
15 | | assessment of the value of the program to both participants and |
16 | | non-participants, and recommendations concerning modification |
17 | | of the program and the tariff or tariffs filed under this |
18 | | Section. This report shall be filed by the electric utility |
19 | | with the Commission within 30 days of receipt and shall be |
20 | | available to the public on the Commission's website. |
21 | | (e) Once the tariff or tariffs has been in effect for 24 |
22 | | months, the Commission may, upon complaint, petition, or its |
23 | | own initiative, open a proceeding to investigate whether |
24 | | changes or modifications to the tariff or tariffs, program |
25 | | administration and any other program design element is |
26 | | necessary to achieve the goals described in subsection (a) of |
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1 | | this Section. Such a proceeding may not last more than 120 days |
2 | | from the date upon which the investigation is opened by |
3 | | Commission order. |
4 | | (f) An electric utility shall be entitled to recover |
5 | | reasonable costs incurred in complying with this Section, |
6 | | provided that recovery of the costs is fairly apportioned among |
7 | | its residential customers. |
8 | | (g) The electric utility's tariff or tariffs filed pursuant |
9 | | to this Section shall be subject to Article IX. |
10 | | (h) This Section does not apply to any electric utility |
11 | | providing service to 100,000 or fewer customers. |
12 | | (220 ILCS 5/16-107.8 new) |
13 | | Sec. 16-107.8. Beneficial electrification. |
14 | | (a) The purpose of this Section is to decrease reliance on |
15 | | fossil fuels and to ensure that electric vehicle adoption and |
16 | | increased electricity usage demand do not place significant |
17 | | additional burdens on the electric distribution system. |
18 | | (b) In this Section, "managed charging program" means a |
19 | | program whereby owners of electric vehicles connect their |
20 | | charging infrastructure to a network or software that has the |
21 | | ability to manage the time and level of charge based on the |
22 | | electric distribution grid's current demand, market rates, or |
23 | | availability of clean energy generation. "Managed charging |
24 | | program" includes a program under which owners of electric |
25 | | vehicles participate in a dynamic rate program, such as a |
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1 | | time-of-use, hourly or other program under which rates vary |
2 | | based on time, which is designed to incent vehicle charging at |
3 | | times of lower demand, increased clean energy generation, or |
4 | | efficient use of the electric distribution grid. |
5 | | (c) Within 120 days after the effective date of this |
6 | | amendatory Act of the 101st General Assembly, the Illinois |
7 | | Commerce Commission shall initiate a process whereby the |
8 | | Commission shall develop a forward-looking plan for |
9 | | strategically increasing transportation electrification in the |
10 | | State. The process shall be open and transparent with inclusion |
11 | | of stakeholder interests, including stakeholders representing |
12 | | environmental justice interests. This process shall conclude |
13 | | within 270 days of opening. The plan shall incentivize |
14 | | transportation electrification through beneficial |
15 | | electrification programs, as described in subsection (d), |
16 | | taking into consideration incentives available through the |
17 | | Department of Commerce and Economic Opportunity and other |
18 | | sources. The plan may include specific directives for public |
19 | | utilities in the State that enable transportation |
20 | | electrification or beneficial electrification. The plan should |
21 | | specifically address environmental justice interests and |
22 | | should provide opportunities for residents and businesses in |
23 | | environmental justice communities to directly benefit from |
24 | | transportation electrification. |
25 | | (d) Beneficial electrification programs, as described |
26 | | elsewhere in this Act and in the Electric Vehicle Act, shall be |
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1 | | defined as programs which replace fossil fuel use and improve |
2 | | electric grid operation. Programs should provide for |
3 | | incentives such that customers are encouraged to use |
4 | | electricity at times of low overall system usage or at times |
5 | | when generation from renewable energy sources is high. Programs |
6 | | that qualify as "beneficial electrification programs" include: |
7 | | (1) time-of-use rates under Section 16-107.7; |
8 | | (2) hourly pricing rates; |
9 | | (3) managed charging programs; |
10 | | (4) electric vehicle-to-grid; |
11 | | (5) demand response; |
12 | | (6) renewable energy generation located in close |
13 | | proximity to the intended energy user; and |
14 | | (7) other such programs as defined by the Commission in |
15 | | the stakeholder process described in subsection (b). |
16 | | (220 ILCS 5/16-108.9 new) |
17 | | Sec. 16-108.9. Clean Energy Empowerment Zone pilot |
18 | | projects. |
19 | | (a) The General Assembly finds that it is important to |
20 | | support the rapid transition in the energy sector to put |
21 | | Illinois on a path to 100% renewable energy. This will require |
22 | | leveraging new technologies and solutions to support grid |
23 | | reliability to address issues such as the shift from large, |
24 | | centralized, fossil generation to wind, solar, and distributed |
25 | | energy resources. To that end, the General Assembly sees the |
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1 | | need for developing pilot projects in Clean Energy Empowerment |
2 | | Zones that enhance reliability while facilitating the |
3 | | transition towards clean energy. |
4 | | (b) An electric utility serving more than 100,000 retail |
5 | | customers may propose one or more Clean Energy Empowerment Zone |
6 | | pilot projects to the Illinois Commerce Commission to conduct a |
7 | | competitive procurement for independently-owned energy storage |
8 | | systems to be located in Clean Energy Empowerment Zones. The |
9 | | Commission shall evaluate the projects based on their ability |
10 | | to address present and future reliability needs identified by |
11 | | the Midcontinent Independent System Operator, PJM |
12 | | Interconnection, electric utilities, or independent analysts. |
13 | | In addition to supporting reliability, a qualifying project |
14 | | must support the transition towards or development of clean |
15 | | energy. |
16 | | (c) The Clean Energy Empowerment Zones described in this |
17 | | Section shall be the same as defined by the Department of |
18 | | Commerce and Economic Opportunity in the Clean Energy |
19 | | Empowerment Zones Act. |
20 | | (d) The Clean Energy Empowerment Zone pilot projects shall |
21 | | closely coordinate with actual and expected development of new |
22 | | wind projects and new solar projects as described in Section |
23 | | 1-75 of the Illinois Power Agency Act, electric vehicle |
24 | | adopted, and Community Energy and Climate Plans as defined in |
25 | | the Community Energy and Climate Planning Act. |
26 | | (e) Upon approval of a Clean Energy Empowerment Zone pilot |
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1 | | project by the Illinois Commerce Commission, an electric |
2 | | utility is authorized to enter into a distribution services |
3 | | contract with new energy storage system projects in accordance |
4 | | with the approved project. Nothing in this Section or in the |
5 | | distribution services contract shall preclude the energy |
6 | | storage project from providing additional wholesale market |
7 | | services. |
8 | | (f) An electric utility that elects to undertake the |
9 | | investment described in subsection (b) of this Section may, at |
10 | | its election, recover the costs of such investment through an |
11 | | automatic adjustment clause tariff or through a delivery |
12 | | services charge regardless of how the costs are classified on |
13 | | the utility's books and records of account. |
14 | | (g) To the extent feasible and consistent with State and |
15 | | federal law, the investments made pursuant to this Section |
16 | | shall provide employment opportunities for former workers in |
17 | | fossil fuel industries and participants in the Clean Jobs |
18 | | Workforce Hubs as defined in the Clean Jobs Workforce Hubs Act. |
19 | | (h) Nothing in this Section is intended to limit the |
20 | | ability of any other entity to develop, construct, or install |
21 | | an energy storage system. In addition, nothing in this Section |
22 | | is intended to limit or alter otherwise applicable |
23 | | interconnection requirements. |
24 | | (220 ILCS 5/16-108.13 new) |
25 | | Sec. 16-108.13. Clean Jobs Workforce Hubs. |
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1 | | (a) An electric utility that serves more than 3,000,000 |
2 | | customers in the State shall spend $25,000,000 per year |
3 | | beginning January 1, 2020 to fund the programs across the State |
4 | | associated with Clean Jobs Workforce Hubs as described in the |
5 | | Clean Jobs Workforce Hubs Act and in this Section. The utility |
6 | | shall invest in a network of frontline organizations that |
7 | | provide direct and sustained support for members of |
8 | | economically disadvantaged communities, environmental justice |
9 | | communities, communities of color, returning citizens, foster |
10 | | care communities, and displaced fossil fuel workers to enter |
11 | | and complete the pipeline for clean energy jobs in solar |
12 | | energy, wind energy, energy efficiency, electric vehicles, and |
13 | | related industries. |
14 | | (b) Within 60 days after the effective date of this |
15 | | amendatory Act of the 101st General Assembly, and after a |
16 | | comprehensive stakeholder process that includes |
17 | | representatives from frontline communities, the Illinois |
18 | | Commerce Commission shall select an individual or an |
19 | | organization to be the program administrator to coordinate the |
20 | | work of all or a portion of the work of the Clean Jobs |
21 | | Workforce Hubs. |
22 | | (c) Within 120 Days after the effective date of this |
23 | | amendatory Act of the 101st General Assembly, and after a |
24 | | comprehensive stakeholder process led by the program |
25 | | administrator that includes representatives from frontline |
26 | | communities, an electric utility that serves more than |
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1 | | 3,000,000 customers in the State shall file with the Commission |
2 | | a plan developed by the program administrator to implement this |
3 | | Section. Within 60 days after the plan is filed, the Commission |
4 | | shall enter an order approving the plan if it is consistent |
5 | | with this Section or, if the plan is not consistent with this |
6 | | Section, the Commission shall explain the deficiencies, after |
7 | | which time the utility shall file a new plan developed by the |
8 | | program administrator to address the deficiencies. |
9 | | (220 ILCS 5/16-108.17 new) |
10 | | Sec. 16-108.17. Distribution system planning. |
11 | | (a) It is the policy of the State of Illinois to promote |
12 | | cost-effective distribution system planning that minimizes |
13 | | long-term costs for Illinois customers and supports the |
14 | | achievement of State carbon reduction and energy policy goals. |
15 | | The General Assembly makes the following findings: |
16 | | (1) Investment in infrastructure to support existing |
17 | | and new distributed energy resources creates significant |
18 | | economic development, environmental and public health |
19 | | benefits in the State of Illinois. |
20 | | (2) Distribution system planning is an important tool |
21 | | for the Commission, electric utilities, and stakeholders |
22 | | to identify and support opportunities to maintain and |
23 | | enhance the safety, security, reliability, and resilience |
24 | | of the electricity grid, at fair and reasonable costs, |
25 | | consistent with the state's energy policies. |
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1 | | (3) A distribution system planning process can |
2 | | minimize distribution system costs to consumers while |
3 | | advancing other Illinois energy policy goals by supporting |
4 | | integration of distributed energy resources and the |
5 | | procurement of non-wires alternatives to capital |
6 | | investments. |
7 | | (4) The planning process should maximize the sharing of |
8 | | information, minimize overlap with existing filing |
9 | | requirements to ensure robust stakeholder participation, |
10 | | and recognize the responsibility of the utility to |
11 | | ultimately manage the grid in a safe, reliable manner. |
12 | | (b) Terms used in this Section shall have the same meanings |
13 | | as defined in Sections 16-102, 16-107.6, and 16-108. |
14 | | (c) An electric utility serving more than 100,000 customers |
15 | | on January 1, 2009 shall prepare and file a distribution system |
16 | | investment plan no later than June 1, 2020. Within 45 days |
17 | | after the filing, the Commission shall, with reasonable notice, |
18 | | open an investigation to consider whether the plan meets the |
19 | | objectives defined in subsection (d) and contains the |
20 | | information required by subsection (e). The Commission shall |
21 | | issue a final order approving the plan, with any modifications |
22 | | the Commission deems reasonable and appropriate to achieve the |
23 | | goals of this Section, within 270 days of the plan filing. The |
24 | | final approved plan shall be part of the record used in the |
25 | | Commission proceeding referenced in subsection (e) of Section |
26 | | 16-107.6, provided that investigation has not been completed |
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1 | | prior to the initial filing date referenced in this subsection |
2 | | (c). |
3 | | (d) The plan shall be designed to: |
4 | | (1) ensure optimized utilization of electricity grid |
5 | | assets and resources to minimize total system costs; |
6 | | (2) enable greater customer engagement, empowerment, |
7 | | and options for energy services; |
8 | | (3) move toward the creation of efficient, |
9 | | cost-effective, accessible grid platforms for new |
10 | | products, new services, and opportunities for adoption of |
11 | | new distributed technologies; |
12 | | (4) bring the benefits of grid modernization and the |
13 | | deployment of distributed energy resources to all |
14 | | communities, including economically disadvantaged |
15 | | communities, throughout Illinois; |
16 | | (5) reduce grid congestion to facilitate availability |
17 | | and development of distributed energy resources; |
18 | | (6) provide for the analysis of the cost-effectiveness |
19 | | of proposed system investments; |
20 | | (7) to the maximum extent possible, achieve or support |
21 | | the achievement of greenhouse gas emissions as defined in |
22 | | Section 9.10 of the Environmental Protection Act; and |
23 | | (8) support existing Illinois policy goals promoting |
24 | | the steady long-term growth of energy efficiency, demand |
25 | | response and investments in renewable energy resources. |
26 | | (e) The plan shall contain the following information: |
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1 | | (1) Distribution system planning processes: A |
2 | | description of the utility's distribution system planning |
3 | | process, including: |
4 | | (A) the overview of the process, including |
5 | | frequency and duration of the process, roles and |
6 | | responsibilities of individuals and organizations |
7 | | involved; |
8 | | (B) the description of internal organizational |
9 | | alignment of the process with other internal planning |
10 | | processes; and |
11 | | (C) the description of process alignment with any |
12 | | other external planning process, such as those |
13 | | required by a regional transmission operator. |
14 | | (2) Baseline distribution system data: A discussion |
15 | | detailing the current operating conditions for the |
16 | | distribution utility system, including a detailed |
17 | | description, with supporting data, of system conditions, |
18 | | including asset age and useful life, ratings, loadings, and |
19 | | other characteristics, as well as: |
20 | | (A) distribution system annual loss percentage for |
21 | | the prior year (average of 12 monthly loss |
22 | | percentages); |
23 | | (B) the maximum hourly coincident load (kW) for the |
24 | | distribution system as measured at the interface |
25 | | between the transmission and distribution system; |
26 | | (C) total distribution substation capacity in kVA; |
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1 | | (D) total distribution transformer capacity in |
2 | | kVA; |
3 | | (E) total miles of overhead distribution wire; |
4 | | (F) total miles of underground distribution wire; |
5 | | (G) a list of all high-voltage and low-voltage |
6 | | substations, or circuits, along with the following for |
7 | | each substation: nameplate rating; firm capacity (or |
8 | | max desired peak demand given contingency or |
9 | | redundancies desired); maximum historic peak demand, |
10 | | including specific day and hours of the day which peak |
11 | | load was experienced; average annual peak load growth |
12 | | over the previous 5 years; forecast annual peak load |
13 | | growth over the next 10 years; types of monitoring and |
14 | | control capabilities, or planned additions of such; a |
15 | | summary of existing system visibility and measurement |
16 | | (feeder-level and time) interval and planned |
17 | | visibility improvements; include information on |
18 | | percentage of the system with each level of visibility |
19 | | (such as max/min, daytime/nighttime, monthly/daily |
20 | | reads, automated/manual); and number of customer |
21 | | meters with advanced metering infrastructure/smart |
22 | | meters and those without, planned advanced metering |
23 | | infrastructure investments, and overview of |
24 | | functionality available; and |
25 | | (H) discussion of how IEEE Std. 1547-2018 impacts |
26 | | distribution system planning considerations (e.g. |
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1 | | opportunities and constraints related to |
2 | | interoperability). |
3 | | (3) Financial data. |
4 | | (A) historical distribution system spending for |
5 | | the past 5 years, in each category: age-related |
6 | | replacements and asset renewal; system expansion or |
7 | | upgrades for capacity; system expansion or upgrades |
8 | | for reliability and power quality; and |
9 | | (B) projected distribution system spending for 10 |
10 | | years into the future for the categories listed in |
11 | | paragraph (1), itemizing any non-traditional |
12 | | distribution projects, including: planned distribution |
13 | | capital projects, including drivers for the project, |
14 | | and summary of anticipated changes in historic |
15 | | spending; and provide any available cost-benefit |
16 | | analysis in which the company evaluated a |
17 | | non-traditional distribution system solution to either |
18 | | a capital or operating upgrade or replacement. |
19 | | (4) Distributed energy resource deployment. |
20 | | (A) Discussion of how the impacts of the utility's |
21 | | energy efficiency program impacts are factored into |
22 | | load forecasts at the substation or circuit level. |
23 | | (B) Discussion of how other distributed energy |
24 | | resources are considered in load forecasting and any |
25 | | expected changes in load forecasting methodology. |
26 | | (C) Total costs spent on distributed energy |
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1 | | resource generation installation in the prior year |
2 | | (including application review, responding to |
3 | | inquiries, metering, testing, and make ready costs. |
4 | | (D) Total charges to customers/member installers |
5 | | for distributed energy resource generation |
6 | | installations, in the prior year (including |
7 | | application, metering, and make ready fees. |
8 | | (E) Total nameplate kW of distributed energy |
9 | | resource generation systems that completed |
10 | | interconnection to the system in the prior year. |
11 | | (F) Total number of distributed energy resource |
12 | | generation systems that completed interconnection to |
13 | | the system in the prior year. |
14 | | (G) Current distributed energy resource deployment |
15 | | by type, size, and geographic dispersion (as useful for |
16 | | planning purposes; such as, by planning areas, |
17 | | service/work center areas, and cities. |
18 | | (H) Information on areas of existing or forecasted |
19 | | low, moderate, and high distributed energy resource |
20 | | penetration. |
21 | | (I) List of areas with existing or forecasted |
22 | | abnormal voltage or frequency issues that may benefit |
23 | | from the utilization of advanced inverter technology. |
24 | | (5) Hosting capacity and interconnection requirements: |
25 | | A hosting capacity analysis, made available to the public |
26 | | on a website with mapping and GIS capability, and with |
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1 | | detail at the block level, that includes a detailed and |
2 | | current analysis of how much capacity is available on each |
3 | | substation, circuit, and node for integrating new |
4 | | distributed energy resource as allowed by thermal ratings, |
5 | | protection system limits, power quality standards, and |
6 | | safety standards. The analysis must also include: |
7 | | (A) circuit level maps and downloadable data sets |
8 | | for public use; |
9 | | (B) an assessment of how utility planned |
10 | | investments over the next 5 years will impact the |
11 | | analysis; and |
12 | | (C) a narrative discussion on how the hosting |
13 | | capacity analysis advances customer-sited distributed |
14 | | energy resource (in particular PV and electric storage |
15 | | systems) and how the utility anticipates the analysis |
16 | | identifying interconnection points on the distribution |
17 | | system and necessary distribution upgrades to support |
18 | | the continued development of distributed generation |
19 | | resources. |
20 | | (6) Scenario analysis and forecasting: The plan shall |
21 | | include load forecasts over the next 10 years at the |
22 | | substation and circuit level using dynamic load |
23 | | forecasting utilizing multiple scenarios and probabilistic |
24 | | planning. In particular, the plan shall include the |
25 | | following: |
26 | | (A) Definitions and a discussion of the |
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1 | | development of base-case, medium, and high scenarios |
2 | | regarding increased distributed energy resource |
3 | | deployment. Scenarios shall reflect a reasonable mix |
4 | | of individual distributed energy resource adoption and |
5 | | aggregated or bundled distributed energy resource |
6 | | service types, and shall include the projected load |
7 | | forecast impacts of distributed energy resource |
8 | | investments, including investments in energy |
9 | | efficiency, demand response. The scenario analysis |
10 | | shall include information on the methodologies used to |
11 | | develop the low, medium, and high scenarios, including |
12 | | the distributed energy resource adoption rates, |
13 | | geographic deployment assumptions, expected |
14 | | distributed energy resource load profiles, and any |
15 | | other relevant assumptions factored into the scenario |
16 | | discussion. |
17 | | (B) A discussion of the processes and tools that |
18 | | would be necessary to accommodate the specified levels |
19 | | of distributed energy resource adoption, including |
20 | | whether existing processes and tools would be |
21 | | sufficient. Provide a discussion of the system impacts |
22 | | that may arise from increased distributed energy |
23 | | resource adoption, potential barriers to distributed |
24 | | energy resource integration, and the types of system |
25 | | upgrades that may be necessary to accommodate the |
26 | | distributed energy resource at the listed penetration |
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1 | | levels. |
2 | | (C) A discussion of how present and projected |
3 | | reductions in the demand for energy may result from |
4 | | measures to improve energy efficiency in the |
5 | | industrial, commercial, residential, and energy |
6 | | producing sectors of the utility service territory. |
7 | | (D) Information on anticipated impacts from FERC |
8 | | Order 841 (Electric Storage Participation in Markets |
9 | | Operated by Regional Transmission Organizations and |
10 | | Independent System Operators) and a discussion of |
11 | | potential impacts from the related FERC Docket No. |
12 | | RM18-9-000 (Participation of Distributed Energy |
13 | | Resource Aggregations in Markets Operated by Regional |
14 | | Transmission Organizations and Independent System |
15 | | Operators). |
16 | | (E) Discussion of how the distribution system |
17 | | planning is coordinated with Commission orders |
18 | | regarding the procurement of renewable resources as |
19 | | discussed in Section 16-111.5, energy efficiency plans |
20 | | as discussed in Section 8-103B, distributed generation |
21 | | rebates as discussed in Section 16-107.6, and any other |
22 | | order affecting the goals described in subsection (d) |
23 | | of this Section. |
24 | | (7) Non-wires alternatives analysis: |
25 | | (A) Detailed discussion of all distribution system |
26 | | projects in the coming 10 years that are anticipated to |
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1 | | have a total cost of greater than $1,000,000. For these |
2 | | projects, an analysis of how non-wires alternatives, |
3 | | including increased local energy efficiency beyond |
4 | | what will occur through system-wide programs, demand |
5 | | response, distributed generation, and storage, compare |
6 | | in terms of viability, price, and long-term value shall |
7 | | be included. Such comparisons must include |
8 | | consideration of the benefits of distributed energy |
9 | | resources beyond meeting local reliability needs (for |
10 | | example, avoided energy costs, avoided system capacity |
11 | | costs, avoided transmission costs, and reduced |
12 | | exposure to future environmental regulations). |
13 | | (B) Identification of the project types that would |
14 | | lend themselves to non-traditional solutions (i.e. |
15 | | load relief or reliability). |
16 | | (C) Timelines needed to consider alternatives to |
17 | | any project types that would lend themselves to |
18 | | non-traditional solutions (allowing time for potential |
19 | | request for proposal, response, review, contracting |
20 | | and implementation). |
21 | | (D) The cost threshold of any project type that |
22 | | would need to be met to have a non-traditional solution |
23 | | reviewed. |
24 | | (8) Proposed distribution system investments: The plan |
25 | | shall identify proposed investments, including the reason |
26 | | for investment, projected costs, scope of work, |
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1 | | prioritization, sequencing of investments, and |
2 | | explanations of how planned investments will support the |
3 | | goals described in subsection (d) of this Section. |
4 | | (f) The Commission shall approve, approve with |
5 | | modifications, or reject the plan within 180 days. The |
6 | | Commission may approve the plan if it finds that the plan will |
7 | | achieve the goals described in subsection (d) of this Section. |
8 | | Proceedings under this Section shall proceed according to the |
9 | | rules provided by Article IX of this Act (9-201). Information |
10 | | contained in the approved plan shall be considered part of the |
11 | | record in any Commission proceeding under subsection (e) of |
12 | | Section 16-107.6 of this Act. |
13 | | (g) Plan updates: Subsequent to the initial plan approval, |
14 | | the utility shall file an update to the plan on June 1, 2022, |
15 | | and every 24 months thereafter. This update shall describe the |
16 | | distribution system investments made during the prior plan |
17 | | period, the investments planned to be made in the following 24 |
18 | | months, and updates to the information required by subsection |
19 | | (e) of this Section. Within 35 days after the utility files its |
20 | | annual report, the Commission shall, upon complaint, petition, |
21 | | or its own initiative, but with reasonable notice, enter upon |
22 | | an investigation regarding the utility's plan update to ensure |
23 | | that the objectives described in subsection (d) of this Section |
24 | | are being achieved. If the Commission finds, after notice and |
25 | | hearing, that the utility's Plan is materially deficient in any |
26 | | way, the Commission shall issue an order requiring the |
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1 | | participating utility to devise a corrective action plan, |
2 | | subject to Commission approval and oversight, to bring the plan |
3 | | into alignment with the goals of this Section. The Commission's |
4 | | order must be entered within 180 days after the utility files |
5 | | its annual report. The Commission shall have the authority to |
6 | | modify the information required by subsection (e) of this |
7 | | Section provided that modification does not impair the |
8 | | achievement of the goals described in subsection (d) of this |
9 | | Section. |
10 | | (220 ILCS 5/16-111.5) |
11 | | Sec. 16-111.5. Provisions relating to procurement. |
12 | | (a) An electric utility that on December 31, 2005 served at |
13 | | least 100,000 customers in Illinois shall procure power and |
14 | | energy for its eligible retail customers in accordance with the |
15 | | applicable provisions set forth in Section 1-75 of the Illinois |
16 | | Power Agency Act and this Section. Beginning with the delivery |
17 | | year commencing on June 1, 2017, such electric utility shall |
18 | | also procure zero emission credits from zero emission |
19 | | facilities in accordance with the applicable provisions set |
20 | | forth in Section 1-75 of the Illinois Power Agency Act, and, |
21 | | for years beginning on or after June 1, 2017, the utility shall |
22 | | procure renewable energy resources in accordance with the |
23 | | applicable provisions set forth in Section 1-75 of the Illinois |
24 | | Power Agency Act and this Section. Beginning with the delivery |
25 | | year commencing on June 1, 2022, if possible, but no later than |
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1 | | for the delivery year commencing June 1, 2023, an electric |
2 | | utility that on December 31, 2005 served at least 3,000,000 |
3 | | customers in Illinois shall procure capacity for its retail |
4 | | customers in accordance with the applicable provisions set for |
5 | | in Section 1-75 of the Illinois Power Agency Act and this |
6 | | Section. A small multi-jurisdictional electric utility that on |
7 | | December 31, 2005 served less than 100,000 customers in |
8 | | Illinois may elect to procure power and energy for all or a |
9 | | portion of its eligible Illinois retail customers in accordance |
10 | | with the applicable provisions set forth in this Section and |
11 | | Section 1-75 of the Illinois Power Agency Act. This Section |
12 | | shall not apply to a small multi-jurisdictional utility until |
13 | | such time as a small multi-jurisdictional utility requests the |
14 | | Illinois Power Agency to prepare a procurement plan for its |
15 | | eligible retail customers. "Eligible retail customers" for the |
16 | | purposes of this Section means those retail customers that |
17 | | purchase power and energy from the electric utility under |
18 | | fixed-price bundled service tariffs, other than those retail |
19 | | customers whose service is declared or deemed competitive under |
20 | | Section 16-113 and those other customer groups specified in |
21 | | this Section, including self-generating customers, customers |
22 | | electing hourly pricing, or those customers who are otherwise |
23 | | ineligible for fixed-price bundled tariff service. For those |
24 | | customers that are excluded from the procurement plan's |
25 | | electric supply service requirements, and the utility shall |
26 | | procure any supply requirements, including capacity, ancillary |
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1 | | services, and hourly priced energy, in the applicable markets |
2 | | as needed to serve those customers, provided that the utility |
3 | | may include in its procurement plan load requirements for the |
4 | | load that is associated with those retail customers whose |
5 | | service has been declared or deemed competitive pursuant to |
6 | | Section 16-113 of this Act to the extent that those customers |
7 | | are purchasing power and energy during one of the transition |
8 | | periods identified in subsection (b) of Section 16-113 of this |
9 | | Act. |
10 | | (b) A procurement plan shall be prepared for each electric |
11 | | utility consistent with the applicable requirements of the |
12 | | Illinois Power Agency Act and this Section. For purposes of |
13 | | this Section, Illinois electric utilities that are affiliated |
14 | | by virtue of a common parent company are considered to be a |
15 | | single electric utility. Small multi-jurisdictional utilities |
16 | | may request a procurement plan for a portion of or all of its |
17 | | Illinois load. Each procurement plan shall analyze the |
18 | | projected balance of supply and demand for those retail |
19 | | customers to be included in the plan's electric supply service |
20 | | requirements over a 5-year period, with the first planning year |
21 | | beginning on June 1 of the year following the year in which the |
22 | | plan is filed. The plan shall specifically identify the |
23 | | long-term bundled contracts to be procured, as described in |
24 | | Section 1-75 of the Illinois Power Agency Act, the carbon-free |
25 | | capacity and supply to be procured, as described in Section |
26 | | 1-75 of the Illinois Power Agency Act, and the wholesale |
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1 | | products to be procured following plan approval , and shall |
2 | | follow all the requirements set forth in the Public Utilities |
3 | | Act and all applicable State and federal laws, statutes, rules, |
4 | | or regulations, as well as Commission orders. Nothing in this |
5 | | Section precludes consideration of contracts longer than 5 |
6 | | years and related forecast data. Unless specified otherwise in |
7 | | this Section, in the procurement plan or in the implementing |
8 | | tariff, any procurement occurring in accordance with this plan |
9 | | shall be competitively bid through a request for proposals |
10 | | process. Approval and implementation of the procurement plan |
11 | | shall be subject to review and approval by the Commission |
12 | | according to the provisions set forth in this Section. A |
13 | | procurement plan shall include each of the following |
14 | | components: |
15 | | (1) Hourly load analysis. This analysis shall include: |
16 | | (i) multi-year historical analysis of hourly |
17 | | loads; |
18 | | (ii) switching trends and competitive retail |
19 | | market analysis; |
20 | | (iii) known or projected changes to future loads; |
21 | | and |
22 | | (iv) growth forecasts by customer class. |
23 | | (2) Analysis of the impact of any demand side and |
24 | | renewable energy initiatives. This analysis shall include: |
25 | | (i) the impact of demand response programs and |
26 | | energy efficiency programs, both current and |
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1 | | projected; for small multi-jurisdictional utilities, |
2 | | the impact of demand response and energy efficiency |
3 | | programs approved pursuant to Section 8-408 of this |
4 | | Act, both current and projected; and |
5 | | (ii) supply side needs that are projected to be |
6 | | offset by purchases of renewable energy resources, if |
7 | | any. |
8 | | (3) A plan for meeting the expected load requirements |
9 | | that will not be met through preexisting contracts. This |
10 | | plan shall include: |
11 | | (i) definitions of the different Illinois retail |
12 | | customer classes for which supply is being purchased; |
13 | | (ii) the proposed mix of demand-response products |
14 | | for which contracts will be executed during the next |
15 | | year. For small multi-jurisdictional electric |
16 | | utilities that on December 31, 2005 served fewer than |
17 | | 100,000 customers in Illinois, these shall be defined |
18 | | as demand-response products offered in an energy |
19 | | efficiency plan approved pursuant to Section 8-408 of |
20 | | this Act. The cost-effective demand-response measures |
21 | | shall be procured whenever the cost is lower than |
22 | | procuring comparable capacity products, provided that |
23 | | such products shall: |
24 | | (A) be procured by a demand-response provider |
25 | | from those retail customers included in the plan's |
26 | | electric supply service requirements; |
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1 | | (B) at least satisfy the demand-response |
2 | | requirements of the regional transmission |
3 | | organization market in which the utility's service |
4 | | territory is located, including, but not limited |
5 | | to, any applicable capacity or dispatch |
6 | | requirements; |
7 | | (C) provide for customers' participation in |
8 | | the stream of benefits produced by the |
9 | | demand-response products; |
10 | | (D) provide for reimbursement by the |
11 | | demand-response provider of the utility for any |
12 | | costs incurred as a result of the failure of the |
13 | | supplier of such products to perform its |
14 | | obligations thereunder; and |
15 | | (E) meet the same credit requirements as apply |
16 | | to suppliers of capacity, in the applicable |
17 | | regional transmission organization market; |
18 | | (iii) monthly forecasted system supply |
19 | | requirements, including expected minimum, maximum, and |
20 | | average values for the planning period; |
21 | | (iv) the proposed mix and selection of standard |
22 | | wholesale products for which contracts will be |
23 | | executed during the next year, separately or in |
24 | | combination, to meet that portion of its load |
25 | | requirements not met through pre-existing contracts or |
26 | | new bundled contracts, as described in Section 1-75 of |
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1 | | the Illinois Power Agency Act , including , but not |
2 | | limited to , monthly 5 x 16 peak period block energy, |
3 | | monthly off-peak wrap energy, monthly 7 x 24 energy, |
4 | | annual 5 x 16 energy, annual off-peak wrap energy, |
5 | | annual 7 x 24 energy, monthly capacity, annual |
6 | | capacity, peak load capacity obligations, capacity |
7 | | purchase plan, and ancillary services; |
8 | | (v) proposed term structures for each wholesale |
9 | | product type included in the proposed procurement plan |
10 | | portfolio of products; and |
11 | | (vi) an assessment of the price risk, load |
12 | | uncertainty, and other factors that are associated |
13 | | with the proposed procurement plan; this assessment, |
14 | | to the extent possible, shall include an analysis of |
15 | | the following factors: contract terms, time frames for |
16 | | securing products or services, fuel costs, weather |
17 | | patterns, transmission costs, market conditions, and |
18 | | the governmental regulatory environment; the proposed |
19 | | procurement plan shall also identify alternatives for |
20 | | those portfolio measures that are identified as having |
21 | | significant price risk. |
22 | | (vii) the amount of supply procured from bundled |
23 | | contracts, as described in Section 1-75 of the Illinois |
24 | | Power Agency Act, and the amount of supply expected to |
25 | | be procured during the next year from new bundled |
26 | | contracts; |
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1 | | (viii) the amount of capacity procured from |
2 | | bundled contracts, as described in Section 1-75 of the |
3 | | Illinois Power Agency Act, and the amount of capacity |
4 | | to be procured during the next year from new bundled |
5 | | contracts. |
6 | | (ix) the amount of capacity procured from |
7 | | carbon-free capacity pursuant to Section 1-75 of the |
8 | | Illinois Power Agency Act and this Section, and the |
9 | | amount of capacity to be procured during the next year |
10 | | from eligible carbon-free resources. |
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 | | (c) The procurement process set forth in Section 1-75 of |
12 | | the Illinois Power Agency Act and subsection (e) of this |
13 | | Section shall be administered by a procurement administrator |
14 | | and monitored by a procurement monitor. |
15 | | (1) The procurement administrator shall: |
16 | | (i) design the final procurement process in |
17 | | accordance with Section 1-75 of the Illinois Power |
18 | | Agency Act and subsection (e) of this Section following |
19 | | Commission approval of the procurement plan; |
20 | | (ii) develop benchmarks in accordance with |
21 | | subsection (e)(3) to be used to evaluate bids; these |
22 | | benchmarks shall be submitted to the Commission for |
23 | | review and approval on a confidential basis prior to |
24 | | the procurement event; |
25 | | (iii) serve as the interface between the electric |
26 | | utility and suppliers; |
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1 | | (iv) manage the bidder pre-qualification and |
2 | | registration process; |
3 | | (v) obtain the electric utilities' agreement to |
4 | | the final form of all supply contracts and credit |
5 | | collateral agreements; |
6 | | (vi) administer the request for proposals process; |
7 | | (vii) have the discretion to negotiate to |
8 | | determine whether bidders are willing to lower the |
9 | | price of bids that meet the benchmarks approved by the |
10 | | Commission; any post-bid negotiations with bidders |
11 | | shall be limited to price only and shall be completed |
12 | | within 24 hours after opening the sealed bids and shall |
13 | | be conducted in a fair and unbiased manner; in |
14 | | conducting the negotiations, there shall be no |
15 | | disclosure of any information derived from proposals |
16 | | submitted by competing bidders; if information is |
17 | | disclosed to any bidder, it shall be provided to all |
18 | | competing bidders; |
19 | | (viii) maintain confidentiality of supplier and |
20 | | bidding information in a manner consistent with all |
21 | | applicable laws, rules, regulations, and tariffs; |
22 | | (ix) submit a confidential report to the |
23 | | Commission recommending acceptance or rejection of |
24 | | bids; |
25 | | (x) notify the utility of contract counterparties |
26 | | and contract specifics; and |
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1 | | (xi) administer related contingency procurement |
2 | | events. |
3 | | (2) The procurement monitor, who shall be retained by |
4 | | the Commission, shall: |
5 | | (i) monitor interactions among the procurement |
6 | | administrator, suppliers, and utility; |
7 | | (ii) monitor and report to the Commission on the |
8 | | progress of the procurement process; |
9 | | (iii) provide an independent confidential report |
10 | | to the Commission regarding the results of the |
11 | | procurement event; |
12 | | (iv) assess compliance with the procurement plans |
13 | | approved by the Commission for each utility that on |
14 | | December 31, 2005 provided electric service to at least |
15 | | 100,000 customers in Illinois and for each small |
16 | | multi-jurisdictional utility that on December 31, 2005 |
17 | | served less than 100,000 customers in Illinois; |
18 | | (v) preserve the confidentiality of supplier and |
19 | | bidding information in a manner consistent with all |
20 | | applicable laws, rules, regulations, and tariffs; |
21 | | (vi) provide expert advice to the Commission and |
22 | | consult with the procurement administrator regarding |
23 | | issues related to procurement process design, rules, |
24 | | protocols, and policy-related matters; and |
25 | | (vii) consult with the procurement administrator |
26 | | regarding the development and use of benchmark |
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1 | | criteria, standard form contracts, credit policies, |
2 | | and bid documents. |
3 | | (d) Except as provided in subsection (j), the planning |
4 | | process shall be conducted as follows: |
5 | | (1) Beginning in 2008, each Illinois utility procuring |
6 | | power pursuant to this Section shall annually provide a |
7 | | range of load forecasts to the Illinois Power Agency by |
8 | | July 15 of each year, or such other date as may be required |
9 | | by the Commission or Agency. The load forecasts shall cover |
10 | | the 5-year procurement planning period for the next |
11 | | procurement plan and shall include hourly data |
12 | | representing a high-load, low-load, and expected-load |
13 | | scenario for the load of those retail customers included in |
14 | | the plan's electric supply service requirements. The |
15 | | utility shall provide supporting data and assumptions for |
16 | | each of the scenarios.
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17 | | (2) Beginning in 2008, the Illinois Power Agency shall |
18 | | prepare a procurement plan by August 15th of each year, or |
19 | | such other date as may be required by the Commission. The |
20 | | procurement plan shall identify the portfolio of |
21 | | demand-response and power and energy products to be |
22 | | procured. Cost-effective demand-response measures shall be |
23 | | procured as set forth in item (iii) of subsection (b) of |
24 | | this Section. Copies of the procurement plan shall be |
25 | | posted and made publicly available on the Agency's and |
26 | | Commission's websites, and copies shall also be provided to |
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1 | | each affected electric utility. An affected utility shall |
2 | | have 30 days following the date of posting to provide |
3 | | comment to the Agency on the procurement plan. Other |
4 | | interested entities also may comment on the procurement |
5 | | plan. All comments submitted to the Agency shall be |
6 | | specific, supported by data or other detailed analyses, |
7 | | and, if objecting to all or a portion of the procurement |
8 | | plan, accompanied by specific alternative wording or |
9 | | proposals. All comments shall be posted on the Agency's and |
10 | | Commission's websites. During this 30-day comment period, |
11 | | the Agency shall hold at least one public hearing within |
12 | | each utility's service area for the purpose of receiving |
13 | | public comment on the procurement plan. Within 14 days |
14 | | following the end of the 30-day review period, the Agency |
15 | | shall revise the procurement plan as necessary based on the |
16 | | comments received and file the procurement plan with the |
17 | | Commission and post the procurement plan on the websites. |
18 | | (3) Within 5 days after the filing of the procurement |
19 | | plan, any person objecting to the procurement plan shall |
20 | | file an objection with the Commission. Within 10 days after |
21 | | the filing, the Commission shall determine whether a |
22 | | hearing is necessary. The Commission shall enter its order |
23 | | confirming or modifying the procurement plan within 90 days |
24 | | after the filing of the procurement plan by the Illinois |
25 | | Power Agency. |
26 | | (4) The Commission shall approve the procurement plan, |
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1 | | including expressly the forecast used in the procurement |
2 | | plan, if the Commission determines that it will ensure |
3 | | adequate, reliable, affordable, efficient, and |
4 | | environmentally sustainable electric service at the lowest |
5 | | total cost over time, taking into account any benefits of |
6 | | price stability. |
7 | | (e) The procurement process shall include each of the |
8 | | following components: |
9 | | (1) Solicitation, pre-qualification, and registration |
10 | | of bidders. The procurement administrator shall |
11 | | disseminate information to potential bidders to promote a |
12 | | procurement event, notify potential bidders that the |
13 | | procurement administrator may enter into a post-bid price |
14 | | negotiation with bidders that meet the applicable |
15 | | benchmarks, provide supply requirements, and otherwise |
16 | | explain the competitive procurement process. In addition |
17 | | to such other publication as the procurement administrator |
18 | | determines is appropriate, this information shall be |
19 | | posted on the Illinois Power Agency's and the Commission's |
20 | | websites. The procurement administrator shall also |
21 | | administer the prequalification process, including |
22 | | evaluation of credit worthiness, compliance with |
23 | | procurement rules, and agreement to the standard form |
24 | | contract developed pursuant to paragraph (2) of this |
25 | | subsection (e). The procurement administrator shall then |
26 | | identify and register bidders to participate in the |
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1 | | procurement event. |
2 | | (2) Standard contract forms and credit terms and |
3 | | instruments. The procurement administrator, in |
4 | | consultation with the utilities, the Commission, and other |
5 | | interested parties and subject to Commission oversight, |
6 | | shall develop and provide standard contract forms for the |
7 | | supplier contracts that meet generally accepted industry |
8 | | practices. Standard credit terms and instruments that meet |
9 | | generally accepted industry practices shall be similarly |
10 | | developed. The procurement administrator shall make |
11 | | available to the Commission all written comments it |
12 | | receives on the contract forms, credit terms, or |
13 | | instruments. If the procurement administrator cannot reach |
14 | | agreement with the applicable electric utility as to the |
15 | | contract terms and conditions, the procurement |
16 | | administrator must notify the Commission of any disputed |
17 | | terms and the Commission shall resolve the dispute. The |
18 | | terms of the contracts shall not be subject to negotiation |
19 | | by winning bidders, and the bidders must agree to the terms |
20 | | of the contract in advance so that winning bids are |
21 | | selected solely on the basis of price. |
22 | | (3) Establishment of a market-based price benchmark. |
23 | | As part of the development of the procurement process, the |
24 | | procurement administrator, in consultation with the |
25 | | Commission staff, Agency staff, and the procurement |
26 | | monitor, shall establish benchmarks for evaluating the |
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1 | | final prices in the contracts for each of the products that |
2 | | will be procured through the procurement process. The |
3 | | benchmarks shall be based on price data for similar |
4 | | products for the same delivery period and same delivery |
5 | | hub, or other delivery hubs after adjusting for that |
6 | | difference. The price benchmarks may also be adjusted to |
7 | | take into account differences between the information |
8 | | reflected in the underlying data sources and the specific |
9 | | products and procurement process being used to procure |
10 | | power for the Illinois utilities. The benchmarks shall be |
11 | | confidential but shall be provided to, and will be subject |
12 | | to Commission review and approval, prior to a procurement |
13 | | event. |
14 | | (4) Request for proposals competitive procurement |
15 | | process. The procurement administrator shall design and |
16 | | issue a request for proposals to supply electricity in |
17 | | accordance with each utility's procurement plan, as |
18 | | approved by the Commission. The request for proposals shall |
19 | | set forth a procedure for sealed, binding commitment |
20 | | bidding with pay-as-bid settlement, and provision for |
21 | | selection of bids on the basis of price. |
22 | | (5) A plan for implementing contingencies in the event |
23 | | of supplier default or failure of the procurement process |
24 | | to fully meet the expected load requirement due to |
25 | | insufficient supplier participation, Commission rejection |
26 | | of results, or any other cause. |
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1 | | (i) Event of supplier default: In the event of |
2 | | supplier default, the utility shall review the |
3 | | contract of the defaulting supplier to determine if the |
4 | | amount of supply is 200 megawatts or greater, and if |
5 | | there are more than 60 days remaining of the contract |
6 | | term. If both of these conditions are met, and the |
7 | | default results in termination of the contract, the |
8 | | utility shall immediately notify the Illinois Power |
9 | | Agency that a request for proposals must be issued to |
10 | | procure replacement power, and the procurement |
11 | | administrator shall run an additional procurement |
12 | | event. If the contracted supply of the defaulting |
13 | | supplier is less than 200 megawatts or there are less |
14 | | than 60 days remaining of the contract term, the |
15 | | utility shall procure power and energy from the |
16 | | applicable regional transmission organization market, |
17 | | including ancillary services, capacity, and day-ahead |
18 | | or real time energy, or both, for the duration of the |
19 | | contract term to replace the contracted supply; |
20 | | provided, however, that if a needed product is not |
21 | | available through the regional transmission |
22 | | organization market it shall be purchased from the |
23 | | wholesale market. |
24 | | (ii) Failure of the procurement process to fully |
25 | | meet the expected load requirement: If the procurement |
26 | | process fails to fully meet the expected load |
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1 | | requirement due to insufficient supplier participation |
2 | | or due to a Commission rejection of the procurement |
3 | | results, the procurement administrator, the |
4 | | procurement monitor, and the Commission staff shall |
5 | | meet within 10 days to analyze potential causes of low |
6 | | supplier interest or causes for the Commission |
7 | | decision. If changes are identified that would likely |
8 | | result in increased supplier participation, or that |
9 | | would address concerns causing the Commission to |
10 | | reject the results of the prior procurement event, the |
11 | | procurement administrator may implement those changes |
12 | | and rerun the request for proposals process according |
13 | | to a schedule determined by those parties and |
14 | | consistent with Section 1-75 of the Illinois Power |
15 | | Agency Act and this subsection. In any event, a new |
16 | | request for proposals process shall be implemented by |
17 | | the procurement administrator within 90 days after the |
18 | | determination that the procurement process has failed |
19 | | to fully meet the expected load requirement. |
20 | | (iii) In all cases where there is insufficient |
21 | | supply provided under contracts awarded through the |
22 | | procurement process to fully meet the electric |
23 | | utility's load requirement, the utility shall meet the |
24 | | load requirement by procuring power and energy from the |
25 | | applicable regional transmission organization market, |
26 | | including ancillary services, capacity, and day-ahead |
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1 | | or real time energy, or both; provided, however, that |
2 | | if a needed product is not available through the |
3 | | regional transmission organization market it shall be |
4 | | purchased from the wholesale market. |
5 | | (6) The procurement process described in this |
6 | | subsection is exempt from the requirements of the Illinois |
7 | | Procurement Code, pursuant to Section 20-10 of that Code. |
8 | | (f) Within 2 business days after opening the sealed bids, |
9 | | the procurement administrator shall submit a confidential |
10 | | report to the Commission. The report shall contain the results |
11 | | of the bidding for each of the products along with the |
12 | | procurement administrator's recommendation for the acceptance |
13 | | and rejection of bids based on the price benchmark criteria and |
14 | | other factors observed in the process. The procurement monitor |
15 | | also shall submit a confidential report to the Commission |
16 | | within 2 business days after opening the sealed bids. The |
17 | | report shall contain the procurement monitor's assessment of |
18 | | bidder behavior in the process as well as an assessment of the |
19 | | procurement administrator's compliance with the procurement |
20 | | process and rules. The Commission shall review the confidential |
21 | | reports submitted by the procurement administrator and |
22 | | procurement monitor, and shall accept or reject the |
23 | | recommendations of the procurement administrator within 2 |
24 | | business days after receipt of the reports. |
25 | | (g) Within 3 business days after the Commission decision |
26 | | approving the results of a procurement event, the utility shall |
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1 | | enter into binding contractual arrangements with the winning |
2 | | suppliers using the standard form contracts; except that the |
3 | | utility shall not be required either directly or indirectly to |
4 | | execute the contracts if a tariff that is consistent with |
5 | | subsection (l) of this Section has not been approved and placed |
6 | | into effect for that utility. |
7 | | (h) The names of the successful bidders and the load |
8 | | weighted average of the winning bid prices for each contract |
9 | | type and for each contract term shall be made available to the |
10 | | public at the time of Commission approval of a procurement |
11 | | event. The Commission, the procurement monitor, the |
12 | | procurement administrator, the Illinois Power Agency, and all |
13 | | participants in the procurement process shall maintain the |
14 | | confidentiality of all other supplier and bidding information |
15 | | in a manner consistent with all applicable laws, rules, |
16 | | regulations, and tariffs. Confidential information, including |
17 | | the confidential reports submitted by the procurement |
18 | | administrator and procurement monitor pursuant to subsection |
19 | | (f) of this Section, shall not be made publicly available and |
20 | | shall not be discoverable by any party in any proceeding, |
21 | | absent a compelling demonstration of need, nor shall those |
22 | | reports be admissible in any proceeding other than one for law |
23 | | enforcement purposes. |
24 | | (i) Within 2 business days after a Commission decision |
25 | | approving the results of a procurement event or such other date |
26 | | as may be required by the Commission from time to time, the |
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1 | | utility shall file for informational purposes with the |
2 | | Commission its actual or estimated retail supply charges, as |
3 | | applicable, by customer supply group reflecting the costs |
4 | | associated with the procurement and computed in accordance with |
5 | | the tariffs filed pursuant to subsection (l) of this Section |
6 | | and approved by the Commission. |
7 | | (j) Within 60 days following August 28, 2007 (the effective |
8 | | date of Public Act 95-481), each electric utility that on |
9 | | December 31, 2005 provided electric service to at least 100,000 |
10 | | customers in Illinois shall prepare and file with the |
11 | | Commission an initial procurement plan, which shall conform in |
12 | | all material respects to the requirements of the procurement |
13 | | plan set forth in subsection (b); provided, however, that the |
14 | | Illinois Power Agency Act shall not apply to the initial |
15 | | procurement plan prepared pursuant to this subsection. The |
16 | | initial procurement plan shall identify the portfolio of power |
17 | | and energy products to be procured and delivered for the period |
18 | | June 2008 through May 2009, and shall identify the proposed |
19 | | procurement administrator, who shall have the same experience |
20 | | and expertise as is required of a procurement administrator |
21 | | hired pursuant to Section 1-75 of the Illinois Power Agency |
22 | | Act. Copies of the procurement plan shall be posted and made |
23 | | publicly available on the Commission's website. The initial |
24 | | procurement plan may include contracts for renewable resources |
25 | | that extend beyond May 2009. |
26 | | (i) Within 14 days following filing of the initial |
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1 | | procurement plan, any person may file a detailed objection |
2 | | with the Commission contesting the procurement plan |
3 | | submitted by the electric utility. All objections to the |
4 | | electric utility's plan shall be specific, supported by |
5 | | data or other detailed analyses. The electric utility may |
6 | | file a response to any objections to its procurement plan |
7 | | within 7 days after the date objections are due to be |
8 | | filed. Within 7 days after the date the utility's response |
9 | | is due, the Commission shall determine whether a hearing is |
10 | | necessary. If it determines that a hearing is necessary, it |
11 | | shall require the hearing to be completed and issue an |
12 | | order on the procurement plan within 60 days after the |
13 | | filing of the procurement plan by the electric utility. |
14 | | (ii) The order shall approve or modify the procurement |
15 | | plan, approve an independent procurement administrator, |
16 | | and approve or modify the electric utility's tariffs that |
17 | | are proposed with the initial procurement plan. The |
18 | | Commission shall approve the procurement plan if the |
19 | | Commission determines that it will ensure adequate, |
20 | | reliable, affordable, efficient, and environmentally |
21 | | sustainable electric service at the lowest total cost over |
22 | | time, taking into account any benefits of price stability. |
23 | | (k) (Blank). |
24 | | (k-5) (Blank). |
25 | | (l) An electric utility shall recover its costs incurred |
26 | | under this Section, including, but not limited to, the costs of |
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1 | | procuring power and energy demand-response resources under |
2 | | this Section. The utility shall file with the initial |
3 | | procurement plan its proposed tariffs through which its costs |
4 | | of procuring power that are incurred pursuant to a |
5 | | Commission-approved procurement plan and those other costs |
6 | | identified in this subsection (l), will be recovered. The |
7 | | tariffs shall include a formula rate or charge designed to pass |
8 | | through both the costs incurred by the utility in procuring a |
9 | | supply of electric power and energy for the applicable customer |
10 | | classes with no mark-up or return on the price paid by the |
11 | | utility for that supply, plus any just and reasonable costs |
12 | | that the utility incurs in arranging and providing for the |
13 | | supply of electric power and energy. The formula rate or charge |
14 | | shall also contain provisions that ensure that its application |
15 | | does not result in over or under recovery due to changes in |
16 | | customer usage and demand patterns, and that provide for the |
17 | | correction, on at least an annual basis, of any accounting |
18 | | errors that may occur. A utility shall recover through the |
19 | | tariff all reasonable costs incurred to implement or comply |
20 | | with any procurement plan that is developed and put into effect |
21 | | pursuant to Section 1-75 of the Illinois Power Agency Act and |
22 | | this Section, including any fees assessed by the Illinois Power |
23 | | Agency, costs associated with load balancing, and contingency |
24 | | plan costs. The electric utility shall also recover its full |
25 | | costs of procuring electric supply for which it contracted |
26 | | before the effective date of this Section in conjunction with |
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1 | | the provision of full requirements service under fixed-price |
2 | | bundled service tariffs subsequent to December 31, 2006. All |
3 | | such costs shall be deemed to have been prudently incurred. The |
4 | | pass-through tariffs that are filed and approved pursuant to |
5 | | this Section shall not be subject to review under, or in any |
6 | | way limited by, Section 16-111(i) of this Act. All of the costs |
7 | | incurred by the electric utility associated with the purchase |
8 | | of zero emission credits in accordance with subsection (d-5) of |
9 | | Section 1-75 of the Illinois Power Agency Act and, beginning |
10 | | June 1, 2017, all of the costs incurred by the electric utility |
11 | | associated with the purchase of renewable energy resources in |
12 | | accordance with Sections 1-56 and 1-75 of the Illinois Power |
13 | | Agency Act, shall be recovered through the electric utility's |
14 | | tariffed charges applicable to all of its retail customers, as |
15 | | specified in subsection (k) of Section 16-108 of this Act, and |
16 | | shall not be recovered through the electric utility's tariffed |
17 | | charges for electric power and energy supply to its eligible |
18 | | retail customers. |
19 | | (m) The Commission has the authority to adopt rules to |
20 | | carry out the provisions of this Section. For the public |
21 | | interest, safety, and welfare, the Commission also has |
22 | | authority to adopt rules to carry out the provisions of this |
23 | | Section on an emergency basis immediately following August 28, |
24 | | 2007 (the effective date of Public Act 95-481). |
25 | | (n) Notwithstanding any other provision of this Act, any |
26 | | affiliated electric utilities that submit a single procurement |
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1 | | plan covering their combined needs may procure for those |
2 | | combined needs in conjunction with that plan, and may enter |
3 | | jointly into power supply contracts, purchases, and other |
4 | | procurement arrangements, and allocate capacity and energy and |
5 | | cost responsibility therefor among themselves in proportion to |
6 | | their requirements. |
7 | | (o) On or before June 1 of each year, the Commission shall |
8 | | hold an informal hearing for the purpose of receiving comments |
9 | | on the prior year's procurement process and any recommendations |
10 | | for change.
|
11 | | (p) An electric utility subject to this Section may propose |
12 | | to invest, lease, own, or operate an electric generation |
13 | | facility as part of its procurement plan, provided the utility |
14 | | demonstrates that such facility is the least-cost option to |
15 | | provide electric service to those retail customers included in |
16 | | the plan's electric supply service requirements. If the |
17 | | facility is shown to be the least-cost option and is included |
18 | | in a procurement plan prepared in accordance with Section 1-75 |
19 | | of the Illinois Power Agency Act and this Section, then the |
20 | | electric utility shall make a filing pursuant to Section 8-406 |
21 | | of this Act, and may request of the Commission any statutory |
22 | | relief required thereunder. If the Commission grants all of the |
23 | | necessary approvals for the proposed facility, such supply |
24 | | shall thereafter be considered as a pre-existing contract under |
25 | | subsection (b) of this Section. The Commission shall in any |
26 | | order approving a proposal under this subsection specify how |
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1 | | the utility will recover the prudently incurred costs of |
2 | | investing in, leasing, owning, or operating such generation |
3 | | facility through just and reasonable rates charged to those |
4 | | retail customers included in the plan's electric supply service |
5 | | requirements. Cost recovery for facilities included in the |
6 | | utility's procurement plan pursuant to this subsection shall |
7 | | not be subject to review under or in any way limited by the |
8 | | provisions of Section 16-111(i) of this Act. Nothing in this |
9 | | Section is intended to prohibit a utility from filing for a |
10 | | fuel adjustment clause as is otherwise permitted under Section |
11 | | 9-220 of this Act.
|
12 | | (q) If the Illinois Power Agency filed with the Commission, |
13 | | under Section 16-111.5 of this Act, its proposed procurement |
14 | | plan for the period commencing June 1, 2017, and the Commission |
15 | | has not yet entered its final order approving the plan on or |
16 | | before the effective date of this amendatory Act of the 99th |
17 | | General Assembly, then the Illinois Power Agency shall file a |
18 | | notice of withdrawal with the Commission, after the effective |
19 | | date of this amendatory Act of the 99th General Assembly, to |
20 | | withdraw the proposed procurement of renewable energy |
21 | | resources to be approved under the plan, other than the |
22 | | procurement of renewable energy credits from distributed |
23 | | renewable energy generation devices using funds previously |
24 | | collected from electric utilities' retail customers that take |
25 | | service pursuant to electric utilities' hourly pricing tariff |
26 | | or tariffs and, for an electric utility that serves less than |
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1 | | 100,000 retail customers in the State, other than the |
2 | | procurement of renewable energy credits from distributed |
3 | | renewable energy generation devices. Upon receipt of the |
4 | | notice, the Commission shall enter an order that approves the |
5 | | withdrawal of the proposed procurement of renewable energy |
6 | | resources from the plan. The initially proposed procurement of |
7 | | renewable energy resources shall not be approved or be the |
8 | | subject of any further hearing, investigation, proceeding, or |
9 | | order of any kind. |
10 | | This amendatory Act of the 99th General Assembly preempts |
11 | | and supersedes any order entered by the Commission that |
12 | | approved the Illinois Power Agency's procurement plan for the |
13 | | period commencing June 1, 2017, to the extent it is |
14 | | inconsistent with the provisions of this amendatory Act of the |
15 | | 99th General Assembly. To the extent any previously entered |
16 | | order approved the procurement of renewable energy resources, |
17 | | the portion of that order approving the procurement shall be |
18 | | void, other than the procurement of renewable energy credits |
19 | | from distributed renewable energy generation devices using |
20 | | funds previously collected from electric utilities' retail |
21 | | customers that take service under electric utilities' hourly |
22 | | pricing tariff or tariffs and, for an electric utility that |
23 | | serves less than 100,000 retail customers in the State, other |
24 | | than the procurement of renewable energy credits for |
25 | | distributed renewable energy generation devices. |
26 | | (Source: P.A. 99-906, eff. 6-1-17 .) |
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1 | | (220 ILCS 5/16-115E new) |
2 | | Sec. 16-115E. Carbon-free supply for alternative retail |
3 | | electric suppliers and electric utilities operating outside |
4 | | their service territories. |
5 | | (a) Beginning in the delivery year that commences on June |
6 | | 1, 2021, an alternative retail electric supplier shall be |
7 | | responsible for procuring cost-effective electricity that has |
8 | | an annual carbon dioxide emissions rate, in pounds of CO2 |
9 | | emissions per megawatt-hour, no greater than the annual targets |
10 | | in subsection (k) of Section 1-75 of the Illinois Power Agency |
11 | | Act. |
12 | | (b) Each alternative retail electric supplier shall, by |
13 | | September 1, 2021 and by September 1 of each year thereafter, |
14 | | prepare and submit to the Commission a public report, in a |
15 | | format to be specified by the Commission, that provides |
16 | | information certifying compliance by the alternative retail |
17 | | electric supplier with this Section, including the source, |
18 | | quantity and hourly CO 2 emissions of supplied electricity, and |
19 | | any other information that the Commission determines necessary |
20 | | to ensure compliance with this Section. |
21 | | (220 ILCS 5/16-128B) |
22 | | Sec. 16-128B. Qualified energy efficiency installers. |
23 | | (a) Within 18 months after the effective date of this |
24 | | amendatory Act of the 99th General Assembly, the Commission |
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1 | | shall adopt rules, including emergency rules, establishing a |
2 | | process for entities installing energy efficiency measures to |
3 | | certify compliance with the requirements of this Section. |
4 | | The process shall include an option to complete the |
5 | | certification electronically by completing forms on-line. An |
6 | | entity installing energy efficiency measures shall be |
7 | | permitted to complete the certification after the subject work |
8 | | has been completed. |
9 | | The Commission shall maintain on its website a list of |
10 | | entities installing energy efficiency measures that have |
11 | | successfully completed the certification process. |
12 | | (b) In addition to any authority granted to the Commission |
13 | | under this Act, the Commission may: |
14 | | (1) determine which entities are subject to |
15 | | certification under this Section; |
16 | | (2) impose reasonable certification fees and |
17 | | penalties; |
18 | | (3) adopt disciplinary procedures; |
19 | | (4) investigate any and all activities subject to this |
20 | | Section, including violations thereof; |
21 | | (5) adopt procedures to issue or renew, or to refuse to |
22 | | issue or renew, a certification or to revoke, suspend, |
23 | | place on probation, reprimand, or otherwise discipline a |
24 | | certified entity under this Act or take other enforcement |
25 | | action against an entity subject to this Section; and |
26 | | (6) prescribe forms to be issued for the administration |
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1 | | and enforcement of this Section. |
2 | | (c) An electric utility may not provide a retail customer |
3 | | with a rebate or other energy efficiency incentive for a |
4 | | measure that exceeds a minimal amount determined by the |
5 | | Commission unless the customer provides the electric utility |
6 | | with (1) a certification that the person installing the energy |
7 | | efficiency measure was a self-installer; or (2) evidence that |
8 | | the energy efficiency measure was installed by an entity |
9 | | certified under this Section that is also in good standing with |
10 | | the Commission. |
11 | | (d) The Commission shall: |
12 | | (1) require entities installing energy efficiency |
13 | | measures to be certified to do business and to be bonded in |
14 | | this State; |
15 | | (2) ensure that entities installing energy efficiency |
16 | | measures have the requisite knowledge, skill, training, |
17 | | experience, and competence to perform functions in a safe |
18 | | and reliable manner as required under subsection (a) of |
19 | | Section 16-128 of this Act; |
20 | | (3) ensure that entities installing energy efficiency |
21 | | measures conform to applicable building and electrical |
22 | | codes; |
23 | | (4) ensure that all entities installing energy |
24 | | efficiency measures meet recognized industry standards as |
25 | | the Commission deems appropriate; |
26 | | (5) include any additional requirements that the |
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1 | | Commission deems reasonable to ensure that entities |
2 | | installing energy efficiency measures meet adequate |
3 | | training, financial, and competency requirements; |
4 | | (6) ensure that all entities installing energy |
5 | | efficiency measures obtain certificates of insurance in |
6 | | sufficient amounts and coverages that the Commission so |
7 | | determines; and |
8 | | (7) identify and determine the training or other |
9 | | programs by which persons or entities may obtain the |
10 | | requisite training, skill, or experience necessary to |
11 | | achieve and maintain compliance with the requirements of |
12 | | this Section. |
13 | | (e) Fees and penalties collected under this Section shall |
14 | | be deposited into the Public Utility Fund and used to fund the |
15 | | Commission's compliance with the obligations imposed by this |
16 | | Section. |
17 | | (f) The rules adopted under this Section shall specify the |
18 | | initial dates for compliance with the rules. |
19 | | (g) For purposes of this Section, entities installing |
20 | | energy efficiency measures shall endeavor to support the |
21 | | diversity goals of this State by attracting, developing, |
22 | | retaining, and providing opportunities to employees of all |
23 | | backgrounds and by supporting female-owned, minority-owned, |
24 | | veteran-owned, and small businesses. Specifically, the |
25 | | Commission shall require that preference must be given to those |
26 | | certified energy efficiency installers who meet multiple |
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1 | | workforce equity building actions, including, but not limited |
2 | | to, the following:
|
3 | | (A) Hiring equity action: 30% of the entity's |
4 | | workforce (measured by FTEs) are people of color |
5 | | (members of a racial or ethnic minority group) and |
6 | | receive at or above the prevailing wage. |
7 | | (B) Clean Jobs Workforce Hubs action: 30% of the |
8 | | workers associated with the project are graduates or |
9 | | trainees from the Clean Jobs Workforce Hubs programs, |
10 | | or equivalent certification, and paid at or above the |
11 | | prevailing wage. |
12 | | (C) Disadvantaged Business Enterprise Action: |
13 | | being an entity defined under Section 2 of the Business |
14 | | Enterprise for Minorities, Women, and Persons with |
15 | | Disabilities Act. |
16 | | (D) Contracting Equity Action: 51% of the entity's |
17 | | subcontractors or vendors are entities defined under |
18 | | Section 2 of the Business Enterprise for Minorities, |
19 | | Women, and Persons with Disabilities Act or 30% of the |
20 | | workers associated with the project, including from |
21 | | all subcontractors and vendors, are people of color |
22 | | (members of a racial or ethnic minority group). |
23 | | (E) Small business action: entity's workforce is |
24 | | comprised of 3 or fewer full-time employees. |
25 | | (Source: P.A. 99-906, eff. 6-1-17 .) |
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1 | | Section 90-25. The Environmental Protection Act is amended |
2 | | by changing Section 9.10 and by adding Sections 4.2 and 13.9 as |
3 | | follows: |
4 | | (415 ILCS 5/4.2 new) |
5 | | Sec. 4.2. Renewable energy benefits. The Illinois |
6 | | Environmental Protection Agency shall conduct a study |
7 | | regarding the ability of solar and wind projects to deliver |
8 | | additional benefits for Illinois such as agriculture and |
9 | | pollinator-friendly projects, brownfield redevelopment, |
10 | | water-pollution buffers, and other land-use or environmental |
11 | | benefits. On or before July 1, 2020, the Agency shall report |
12 | | its findings and recommendations to the General Assembly and to |
13 | | the Governor.
|
14 | | (415 ILCS 5/9.10)
|
15 | | Sec. 9.10. Fossil fuel-fired electric generating plants.
|
16 | | (a) The General Assembly finds and declares that:
|
17 | | (1) fossil fuel-fired electric generating plants are a |
18 | | significant source
of air emissions in this State and have |
19 | | become the subject of a number of
important new studies of |
20 | | their effects on the public health;
|
21 | | (2) existing state and federal policies, that allow |
22 | | older plants that meet
federal standards to operate without |
23 | | meeting the more stringent requirements
applicable to new |
24 | | plants, are being questioned on the basis of their
|
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1 | | environmental impacts and the economic distortions such |
2 | | policies cause in
a deregulated energy market;
|
3 | | (3) fossil fuel-fired electric generating plants are, |
4 | | or may be,
affected by a number of regulatory programs, |
5 | | some of which are under review
or development on the state |
6 | | and national levels, and to a certain extent the
|
7 | | international level, including the federal acid rain |
8 | | program, tropospheric
ozone, mercury
and other hazardous |
9 | | pollutant control requirements, regional haze, and global
|
10 | | warming;
|
11 | | (4) scientific uncertainty regarding the formation of |
12 | | certain components
of regional haze and the air quality |
13 | | modeling that predict impacts of
control measures requires |
14 | | careful consideration of the timing of the
control of some |
15 | | of the pollutants from these facilities, particularly |
16 | | sulfur
dioxides and nitrogen oxides that each interact with |
17 | | ammonia and other
substances in the atmosphere;
|
18 | | (5) the development of energy policies to promote a |
19 | | safe, sufficient,
reliable, and affordable energy supply |
20 | | on the state and national levels is
being affected by the |
21 | | on-going deregulation of the power generation industry
and |
22 | | the evolving energy markets;
|
23 | | (6) the Governor's formation of an Energy Cabinet and |
24 | | the development of a
State energy policy calls for actions |
25 | | by the Agency and the Board that are in
harmony with the |
26 | | energy needs and policy of the State, while protecting the
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1 | | public health and the environment;
|
2 | | (7) reducing greenhouse gas emissions and other air |
3 | | pollutants such as particulate matter, sulfur dioxide, and |
4 | | nitrogen oxide is critical to improving the health and |
5 | | welfare of Illinois residents by decreasing respiratory |
6 | | diseases, cardiovascular diseases, and related |
7 | | mortalities; lowering customers' energy costs; and |
8 | | responding to the growing impacts of climate change from |
9 | | fossil-fuel generation; |
10 | | (8) through reductions in harmful emissions and |
11 | | strategic planning for Illinois citizens currently |
12 | | employed by and communities reliant on fossil-fuel |
13 | | electricity generation units, eliminating greenhouse gas |
14 | | emissions from the electricity generation sector is a |
15 | | priority for the State; |
16 | | (9) The 100th General Assembly recognized this problem |
17 | | and, in passing House Resolution 490 on June 26, 2017, it |
18 | | supported the Paris Climate Agreement and urged the State |
19 | | of Illinois join the United States Climate Alliance and |
20 | | develop a plan to achieve 100% clean energy by 2045;
|
21 | | (7) Illinois coal is an abundant resource and an |
22 | | important component of
Illinois' economy whose use should |
23 | | be encouraged to the greatest extent
possible consistent |
24 | | with protecting the public health and the environment;
|
25 | | (8) renewable forms of energy should be promoted as an |
26 | | important element
of the energy and environmental policies |
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1 | | of the State and that it is a goal of
the State that at |
2 | | least 5% of the State's energy production and use be |
3 | | derived
from renewable forms of energy by 2010 and at least |
4 | | 15% from renewable forms
of energy by 2020;
|
5 | | (10) (9) efforts on the state and federal levels are |
6 | | underway to consider the
multiple environmental |
7 | | regulations affecting electric generating plants in
order |
8 | | to improve the ability of government and the affected |
9 | | industry to engage
in effective planning through the use of |
10 | | multi-pollutant strategies; and
|
11 | | (11) (10) these issues, taken together, call for a |
12 | | comprehensive review of the
impact of these facilities on |
13 | | the public health, considering also the energy
supply, |
14 | | reliability, and costs, the role of renewable forms of |
15 | | energy, and the
developments in federal law and regulations |
16 | | that may affect any state actions,
prior to making final |
17 | | decisions in Illinois.
|
18 | | (b) Taking into account the findings and declarations of |
19 | | the General
Assembly contained in subsection (a) of this |
20 | | Section, the Agency shall, within 180 days after the effective |
21 | | date of this amendatory Act of the 101st General Assembly, |
22 | | initiate a rulemaking to amend Title 35 of the Illinois |
23 | | Administrative Code to establish annual greenhouse gas |
24 | | pollution caps and further co-pollutant reductions beginning |
25 | | in 2020 from electric generating units (including, but not |
26 | | limited to, coal-fired, coal-derived, oil-fired, combustion |
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1 | | turbine, integrated gasification combined cycle, and |
2 | | cogeneration facilities above or below 25 MW) and progressively |
3 | | eliminate all emissions of greenhouse gases, particulate |
4 | | matter, mercury, nitrogen oxides, and sulfur dioxide from |
5 | | Illinois' electric sector by the year 2030. As part of this |
6 | | rulemaking, the Agency shall: |
7 | | (1) ensure that environmental justice communities are |
8 | | protected and develop an environmental justice analysis in |
9 | | partnership with the Illinois Commission on Environmental |
10 | | Justice that includes a cumulative impacts assessment and |
11 | | proposed definition of environmental justice communities |
12 | | based on existing methodologies and findings used by the |
13 | | Illinois Power Agency and its Administrator in its Illinois |
14 | | Solar for All Program; |
15 | | (2) identify electric generating units located in or |
16 | | near environmental justice communities and require more |
17 | | rapid greenhouse gas and co-pollutant emissions reductions |
18 | | of those facilities |
19 | | (3) conduct a robust and inclusive stakeholder process |
20 | | prior to issuing a draft rule to the Illinois Pollution |
21 | | Control Board that includes a formal public comment period |
22 | | with public hearings accessible to working residents; |
23 | | (4) participate in strategic planning efforts with the |
24 | | Department of Commerce and Economic Opportunity to |
25 | | identify needs and initiatives for communities and workers |
26 | | economically impacted by the decline in fossil fuel |
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1 | | generation. |
2 | | before
September 30, 2004, but not before September 30, 2003, |
3 | | issue to the House and
Senate Committees on Environment and |
4 | | Energy findings that address the potential
need for the control |
5 | | or reduction of emissions from fossil fuel-fired electric
|
6 | | generating plants, including the following provisions:
|
7 | | (1) reduction of nitrogen oxide emissions, as |
8 | | appropriate, with
consideration of maximum annual |
9 | | emissions rate limits or establishment of an
emissions |
10 | | trading program and with consideration of the developments |
11 | | in federal
law and
regulations that may affect any State |
12 | | action, prior to making final decisions
in Illinois;
|
13 | | (2) reduction of sulfur dioxide emissions, as |
14 | | appropriate, with
consideration of maximum annual |
15 | | emissions rate limits or establishment of an
emissions |
16 | | trading program and with consideration of the developments |
17 | | in federal
law and regulations that may affect any State |
18 | | action, prior to making final
decisions in Illinois;
|
19 | | (3) incentives to promote renewable sources of energy |
20 | | consistent with
item (8) of subsection (a) of this Section;
|
21 | | (4) reduction of mercury as appropriate, consideration |
22 | | of
the availability of control technology, industry |
23 | | practice requirements, or
incentive programs, or some |
24 | | combination of these approaches that are sufficient
to |
25 | | prevent unacceptable local impacts from individual |
26 | | facilities and with
consideration of the developments in |
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1 | | federal law and
regulations that may affect any state |
2 | | action, prior to making final decisions
in Illinois; and
|
3 | | (5) establishment of a banking system, consistent with |
4 | | the United States
Department of Energy's voluntary |
5 | | reporting system, for certifying credits for
voluntary |
6 | | offsets of emissions of greenhouse gases, as identified by |
7 | | the United
States Environmental Protection Agency, or |
8 | | other voluntary reductions of
greenhouse gases. Such |
9 | | reduction efforts may include, but are not limited to,
|
10 | | carbon sequestration, technology-based control measures, |
11 | | energy efficiency
measures, and the use of renewable energy |
12 | | sources.
|
13 | | The Agency shall consider the impact on the public health, |
14 | | considering also
energy supply, reliability and costs, the role |
15 | | of renewable forms of energy,
and developments in federal law |
16 | | and regulations that may affect any state
actions, prior to |
17 | | making final decisions in Illinois.
|
18 | | (c) Nothing in this Section is intended to or should be |
19 | | interpreted in a
manner to limit or restrict the authority of |
20 | | the Illinois Environmental
Protection Agency to propose, or the |
21 | | Illinois Pollution Control Board to
adopt, any regulations |
22 | | applicable or that may become applicable to the
facilities |
23 | | covered by this Section that are required by federal law.
|
24 | | (d) The Agency may file proposed rules with the Board to |
25 | | effectuate the goals set forth in subsection (b). its
findings |
26 | | provided to the Senate Committee on Environment and Energy and |
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1 | | the
House Committee on Environment and Energy in accordance |
2 | | with subsection (b) of
this Section. Any such proposal shall |
3 | | not be submitted sooner than 90 days
after the issuance of the |
4 | | findings provided for in subsection (b) of this
Section. The |
5 | | Board shall take action on any such proposal within one year of
|
6 | | the Agency's filing of the proposed rules.
|
7 | | (e) This Section shall apply only to those electrical |
8 | | generating units
that are subject to the provisions of Subpart |
9 | | W of Part 217 of Title 35 of
the Illinois Administrative Code, |
10 | | as promulgated by the Illinois Pollution
Control Board on |
11 | | December 21, 2000.
|
12 | | (Source: P.A. 92-12, eff. 7-1-01; 92-279, eff. 8-7-01.)
|
13 | | (415 ILCS 5/13.9 new) |
14 | | Sec. 13.9. Coal ash regulation. |
15 | | (a) In this Section, "coal ash" means coal combustion waste |
16 | | as defined in Section 3.140. |
17 | | (b) Within 180 days after the effective date of this |
18 | | amendatory Act of the 101st General Assembly, the Agency shall |
19 | | initiate a rulemaking to amend 35 Ill. Adm. Code Part 620 to |
20 | | establish and enforce limits on annual coal ash disposal in the |
21 | | State. This rule must include specific enforcement measures |
22 | | that are available to the public if the Agency or a regulated |
23 | | party fails to meet these requirements. Also as part of this |
24 | | rule, the Agency shall set forth a procedure by which owners or |
25 | | operators, or both, of both active and inactive coal ash |