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Yes: 308 • No: 130
IllinoisSB0025104th General Assembly (2025–2026)SenateWALLET
SWIMMING FACILITY COLD SPA
Sponsored By: Steve Stadelman (Democratic)
Became Law
assignmentspublic healthexecutive
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Bill Overview
Analyzed Economic Effects
144 provisions identified: 66 benefits, 12 costs, 66 mixed.
Help after radioactive release losses
If a radioactive release from the regional disposal facility harms you, you can file a claim within 5 years of discovery. The program pays 100% of uninsured medical bills for up to 3 years. It pays 80% of lost wages or business income, up to $15,000 per year for up to 3 years. It pays 80% of property losses and 100% of property cleanup costs. Hearings must be held within 60 days if you ask, and decisions come within 30 days after the hearing. Payments come from the Development and Operation Fund and depend on available money.
Relocation aid for disposal facility projects
The Director can acquire land for the radioactive by‑product disposal facility and relocate existing facilities. The Agency pays relocation costs from the Development and Operation Fund. It may run a relocation program under federal rules and can exceed federal payment caps to secure decent, safe, sanitary housing or a suitable alternate location. This authority takes effect June 1, 2024.
Stronger grid planning at big utilities
Large electric utilities must file Multi‑Year Integrated Grid Plans on a set schedule: first by January 20, 2023, next by January 20, 2026, and then every four years. Plans must show system conditions, five years of financial data, DER inventories and hosting capacity, scenarios, DER benefits, long‑term investment options, and interoperability. If a plan period goes past January 1, 2029, it must include transportation electrification steps like make‑ready work, time‑of‑use rates, and optimized charging.
Big storage grants for old coal sites
The Department can award up to $280.5 million for big battery projects at qualifying former coal sites. Grantees are paid $110,000 per megawatt each year for 10 years, with total yearly program payments capped at $28.05 million. The program can fund up to 3 sites in MISO and up to 2 in PJM. Utilities send monthly collections of the Coal to Solar charge to the State to fund these grants.
Fixed price RECs at former coal sites
The Agency runs REC buys for new renewables at former coal‑plant sites. Selected sellers get $30 per REC under 20‑year contracts, or 15 years for certain PJM projects with at least 1,200 MW prior capacity as of January 1, 2021. The first buy covers 400,000 to 580,000 RECs per year; the second buys up to 625,000 minus the first. First‑event projects must be 20–100 MW with 2–10 MW of storage; second‑event projects are 5–20 MW with 0.5–1 MW of storage. Standard contracts set start dates, payment timing, delivery rules, penalties, and REC retirement.
Power plants face pollution deadlines
The law sets firm cut‑off dates for carbon and related pollution. Nonpublic coal‑ and oil‑fired units must reach zero emissions by January 1, 2030. Public coal units must cut emissions 45% by January 1, 2035 and reach zero by December 31, 2045, with required unit retirements or other steps if they miss the 2035 target. Many gas‑fired units face phased cuts, with some near designated communities at zero by January 1, 2030, and all covered gas units at zero by January 1, 2045.
Stronger guardrails on clean coal deals
The law caps how much extra per‑kWh cost from clean coal can be passed to customers. Contract prices must use a 45% equity and 55% debt capital mix, with an allowed return on equity no higher than 11.5% or the rate the legislature approves. A sourcing deal cannot take effect until a cost report is filed, the Commission reports within six months, the legislature approves prices and bill impacts, and the Commission finishes a 90‑day review. The first clean coal plant must report capture each year; if it captures under 50%, it must buy Illinois offsets, with offset costs capped at $15 million per year.
Storage projects must post cleanup funds
Energy storage owners must secure money for decommissioning based on an Illinois‑licensed engineer’s estimate: 25% before full operation, 50% before year 5, and 100% by year 10. Owners must update the estimate at least every 5 years. If the project ends or is abandoned, equipment must be removed to a 3‑foot depth and the site restored within 18 months. Abandonment includes 12 straight months without storage or not paying the property owner for 6 months, with force majeure exceptions.
Higher nuclear fees and shipment charges
Owners of reactors operating on January 1, 2026 pay a one‑time $500,000 fee per reactor. Annual fees are $3,900,000 per operating reactor, rising 1.5% each year for nine years. New‑site stations with an emergency planning zone must reimburse the Agency’s invoiced equipment costs and pay a $1,400,000 capital surcharge per station. One‑time and annual fees follow set installment schedules, and late payments over 90 days can trigger civil penalties up to 4 times the unpaid amount. Shipment fees apply: trucks $2,500 each plus $25 per mile over 250 miles in Illinois (reduced for short medical‑isotope trips), and rail $4,500 for the first cask and $3,000 for each extra.
Rebates for rooftop solar and batteries
Owners of systems up to 5,000 kW on the customer side of the meter can get a one‑time rebate for grid services. Base amounts are $250 per kW for generation and $250 per kWh for storage. For systems that were eligible for net metering before the threshold date, generation is $300 per kW until December 31, 2029 and $250 per kW starting January 1, 2030. Storage is $300 per kWh until the threshold date and $250 per kWh after. A smart inverter must be installed and operating to qualify. In utility areas with 3,000,000+ customers, PV paired with storage also gets rebates for required interconnection costs and wholesale demand charges if you show proof you participate in the PJM frequency regulation market. Utilities may recover rebate costs under approved rules.
Clean‑energy equity rules and grants
The state runs a Jobs and Environmental Justice grant program with awards up to $1,000,000 per application and up to $41 million yearly. Only equity‑eligible contractors can use the equity category of the Adjustable Block Program. Vendors that miss minimum equity standards are barred from procurements until they complete corrective steps. Equity accountability also applies to energy storage programs. Entities serving more than 10,000 Illinois customers cannot bid in Agency procurements.
Clean coal contracts and requirements
Utilities must sign sourcing agreements with the initial clean coal facility, but the deals only take effect if the General Assembly approves them and other conditions are met. Each utility must contract for at least 5% of its 2015 retail supply from that facility, within statutory limits. The State sets a goal of 25% clean coal by January 1, 2025.
Clean power buying and bill charges
The state plans long‑term renewable buys and, starting June 1, 2017, procures zero‑emission credits. Utilities that meet size thresholds must buy renewables and credits, and from June 1, 2026, storage; very large utilities must buy carbon‑mitigation credits from June 1, 2022. Starting with the delivery year beginning June 1, 2027, procurement plans include energy, capacity, and resource‑adequacy purchases when the Commission identifies a need, with contracts designed to add new supply. Utilities may recover costs for these credits and resources through a uniform cents‑per‑kWh line item with separate tracking, five‑year spend windows, and annual true‑ups.
Utility profits tied to energy savings
The law links big electric utilities’ allowed profit (ROE) to how well they meet yearly energy‑savings goals. Very large utilities can see ROE move up or down by as much as 200 basis points; mid‑size utilities face smaller step‑changes and caps. There is a special formula if a yearly goal is under 0.6% of past sales. Starting in 2027, utilities over 500,000 customers see ongoing ROE changes for energy savings (and for peak demand at mid‑size firms). Utilities must send data within 30 days after the plan year ends; an independent evaluator reports by 120 days; filings are due by 160 days and the Commission’s calculation is final on December 15 unless it issues an order.
Zero‑emission credits: buys and price
Beginning with the delivery year that started June 1, 2017, the state buys zero‑emission credits (ZECs) equal to about 16% of each large utility’s 2014 deliveries. The ZEC price is $16.50 per MWh, adjusted for inflation each year. Starting with the delivery year that began June 1, 2023, the price rises by $1 per MWh each year. If the market price index is above the $31.40/MWh baseline, the ZEC price is cut by that difference. If that cut is as large as the Social Cost of Carbon for the year, no ZEC payments are made that year.
Clearer credits for solar and hourly customers
If you make more power than you use in an hour under hourly or time‑of‑use rates, you get two credits: the hour’s energy price and a delivery credit per kWh. Community subscribers must see money credits for energy, capacity, transmission, and similar charges; utilities must convert non‑kWh charges to a kWh‑equivalent. If you buy power from an alternative supplier, the utility must send your generation info so your credits are applied. You keep ownership of any renewable energy or emission credits your system makes. Utilities must file net metering tariffs within 30 days of the law, and large utilities must also provide a streamlined bill‑crediting system within 90 days; the Commission rules on filings within 120 days.
Easier access to your utility data
Utilities must keep your usage data for 5 years or while billing is active. With your authorization, they must deliver it within 30 days, include required history, and keep sending it at least monthly until you revoke. The Commission adopts a standard authorization form within 180 days. Data delivery is secure and free to the recipient. Large utilities (500,000+ customers) must upload data directly to the benchmarking tool.
Easier net metering and community solar credits
All providers must offer net metering by April 1, 2008. If you make more power than you use, you get 1:1 kilowatt‑hour credits carried to future bills until year‑end. Shared buildings and community projects can qualify if each share is at least 200 watts and the total facility is 5,000 kW or less. Large utilities (over 200,000 customers on Jan 1, 2021) must process applications, manage billing, start credits at commercial operation, and pay community credits at the utility’s total price‑to‑compare. They must transfer banked credits when you change suppliers or ownership. On request, they must offer net crediting and cap the fee charged to the project owner at 2% of the subscription fee credit value. Project owners must send monthly subscriber kWh data in the required format so credits appear on bills.
Easier solar hookups and dispute help
The Commission sets statewide net metering and interconnection rules with clear fees, timelines, and safety, using IEEE 1547 as a guide. Within 90 days of the law, a working group brings utilities, customers, and developers together to fix interconnection problems and report every six months. An Ombudsman helps resolve interconnection disputes with non‑binding arbitration and may charge fees to the party who starts a dispute. Commission staff can lead the working group without affecting active cases.
Geothermal contracts pay more upfront
Geothermal Homes and Businesses Program contracts last 15 years. For residential projects, at least 40% of the contract value is paid when the system is energized. Extra REC generation can carry forward during the 15‑year term. The utility receives and retires RECs paid for in the first 15 years; later RECs are not transferred.
Help for consumer advocates in utility cases
The law creates a fund to pay eligible consumer representatives who take part in utility cases. You can be paid for reasonable attorney and expert costs, and other prep costs, if the Commission finds your work was material and caused serious financial hardship. The administrator can issue upfront payments and later reconcile them. You must file an itemized request within 30 days after the final order or rehearing decision. Starting September 15, 2021, utilities must also deposit up to half of allowed rate‑case attorney and expert costs (cap $500,000), and many utilities made a one‑time payment into the fund within 60 days after that date.
Help with solar interconnection disputes
An Ombudsperson helps customers and developers resolve interconnection problems. Utilities must give records and detailed cost information on request. The Ombudsperson can run a fast, informal dispute process and provide a recommended resolution within 30 days after getting full information.
Lower, standard fee for small interconnections
The Commission sets one standard cost for Level 1 interconnections. The fee cannot be more than $200, set within 90 days of the law. A standing working group studies interconnection issues and must keep the Level 1 fee at or below $200. Initial reports on timelines, hosting maps, and queue management are due within 12 months.
Stronger protections in utility program financing
Before enrolling you, aggregators must tell you what you will be paid, who covers fees or penalties, and who posts collateral. Utilities must run lender RFPs and prefer bids with better rates and fees for participants. Vendors must help with financing applications, lenders do credit checks, and utilities show the charge as a separate line on your bill. The Commission can write rules to run the program. The Agency can design remedies to secure promised vendor payments, push other vendors to help, and pay restitution for proven harm.
Extra payments for projects in equity areas
If your distributed or community renewable project’s interconnection agreement is after the law’s effective date and the site is in an equity investment eligible community when you sign, you get an extra payment on top of rebates. The utility sets the amount by tariff and the Commission must approve it. The Commission must decide proposed rebate tariffs within 240 days.
Extra REC buys favor small systems
The state can spend up to $30 million to buy RECs from new or existing solar projects. For the supplemental REC buy, the Agency aims for 50% of distributed‑generation RECs to come from systems under 25 kW, if available. This helps small home systems sell their credits.
More gas efficiency help for low-income
Starting January 1, 2027, low‑income means income at or below 80% of area median income. Utilities must spend at least the larger of 25% or five points above low‑income customers’ sales share on low‑income programs. At least 80% of that money funds whole‑building weatherization, and up to 15% can cover health and safety work. Utilities must use state and federal weatherization networks where possible and favor proven low‑income contractors. Low‑income programs do not have to pass the TRC cost‑effectiveness test. Some smaller single‑fuel gas utilities may be excepted.
More solar help for low-income homes
The Illinois Solar for All Program provides incentives for rooftop and community solar in low‑income and environmental‑justice communities. The program buys all RECs from each system for the first 15 years to give steady payments. Up to 5% of funds may support community outreach and job training. Initial funds are split 35%/40%/25% across subprograms, and shares can change if money goes unused. Up to 25% of certain subprogram funds can shift to a Storage for All program for batteries paired with solar. If the Fund falls under $5,000 after obligations, remaining money goes to the Low‑Income Energy Assistance Fund. When the rate cap binds, the plan protects funding for Solar for All after existing contracts.
Local governments cannot ban your solar
Counties and cities cannot ban the installation of solar panels or low‑voltage solar devices. If a city owns the local electric system, it may set reasonable interconnection and use rules that follow state utility law.
More free preapprenticeship and navigator help
The Department runs free Illinois Works and Climate Works preapprenticeship programs. Three Climate Works hubs recruit, prescreen, train at no cost, and offer stipends, with set shares reserved for residents of R3 Areas and environmental justice communities. Energy Transition Navigators help people find training, jobs, and small‑business services and report each year. Starting July 1, 2024, the State transfers $27.5 million each year to the Illinois Works Fund to support these efforts.
Prevailing wages on Solar for All jobs
For Solar for All project applications submitted after June 30, 2023, construction and installation must pay at least the state’s prevailing wage. This rule does not apply to single‑family or multi‑family residential projects, or to houses of worship under 100 kW. The Agency may adjust REC prices to reflect higher labor costs.
Bid credits for hiring apprentices
Contractors that employ apprentices who finished the Illinois Works preapprenticeship get bid credits set by the Department. Credits go into a statewide Credit Bank for future public works bids. Firms cannot double‑claim other State bid credits for the same contract, and must show certified payroll hours to earn credits.
Bid boost for local contractors
For utility construction or installation work, contractors get a 2% bid preference if based in the utility’s service area. They get another 2% preference if at least 85% of their workers on the job live in that area. Utilities must also show how vendors will promote workforce equity and quality jobs.
Who counts as equity-eligible people, communities
The law defines equity investment eligible people. It includes graduates and participants of named clean energy training programs, people in or formerly in foster care, people who were incarcerated, and residents of eligible communities. Equity investment eligible communities are R3 Areas and environmental justice communities. These people and places get priority for clean energy investments and program slots.
Stronger checks on utility rate hikes
When a Commission order raises rates to expand or add programs or raise procurement limits, it must tell lawmakers the expected monthly customer costs and savings. Lawmakers can pass a joint resolution to suspend the increases before they start. If that happens, the Commission pauses the order and approves a changed plan within 120 days. In rate cases, the Commission must review whether a utility’s lawyer and expert costs are fair and explain that finding in its final order.
Faster approval of utility grid plans
The Commission must approve, change, or reject each Integrated Grid Plan on deadlines. It acts by December 15, 2023 for first filings, and by December 15 in later filing years. If a plan is rejected, the utility refiles within 3 months and the old plan stays in place. The Commission also uses emergency rulemaking so rules take effect within 90 days of the amendatory Act.
Grants and fund for electric vehicles
Beginning January 1, 2029, the state runs grants and help for electric cars, buses, trucks, charging stations, and education. A draft Transportation Electrification Plan is due by March 1, 2028, then every 3 years, with a final plan within 180 days. Grants follow state grant rules and paid charging work must use prevailing wages. The Electric Vehicle and Charging Rebate Fund receives user fees, other transfers, and appropriations to pay for these programs. The program budget matches the annual utility budgets for 2026–2028.
New resource plans for cities and co-ops
By January 1, 2027 and every five years, municipal power agencies, cities, and electric co‑ops over 7,000 meters must start an integrated resource plan and post a preliminary plan online by January 1 of the next year. Each plan lists generation, contracts, programs, and transmission, gives 20‑year costs, a 5‑year load forecast, and a 5‑year action plan, and includes least‑cost paths to 40% renewables by 2030 and 100% carbon‑free by 2045 consistent with reliability. For the first IRP, utilities must list Inflation Reduction Act programs they use or plan to use. They must hold accessible public meetings, take written comments, respond, and the Illinois Power Agency keeps plans public for 10 years. Co‑ops can use internal or prequalified consultants, and small utilities can apply for planning grants, subject to funding.
State rules and inspections for SMRs
By January 1, 2026, the state sets rules for small modular reactors. The rules cover decommissioning, environmental monitoring, and emergency readiness. Fees must cover regulation and inspections, and can fund local emergency preparedness grants. Inspectors may access sites and records and must follow federal agreements and each reactor’s security plan. Fees go to the Nuclear Safety Emergency Preparedness Fund.
Stronger gas savings programs and equity
Natural gas utilities must hit yearly energy‑savings goals based on 2009 sales. Targets grow over time, reaching 1.5% a year starting in 2019 and each year after. For plans that began before January 1, 2018, utilities used 75% of funds and the state used 25%, with at least 10% from public entities. Utilities should use smart‑meter (AMI) data to plan and check programs, while protecting privacy. Utilities must report each year on workforce and vendor diversity and fix gaps within a year. If some customers opt out, their load does not count toward utility savings targets.
Tighter rules on radioactive waste shipments
The Agency must make and enforce rules under the Radioactive Waste Compact. It must block waste shipments or acceptance that violate the Compact or state law. The Agency may set shipment conditions and civil penalties, with fines deposited in the state fund. It may allow exemptions only if consistent with the Compact.
Up to $20M for thermal energy pilots
The Commission works with the Illinois Finance Authority to fund thermal energy network pilot projects. If federal money is not available or not enough, up to $20 million can be allocated to the Authority for grants or financing, including admin costs. The Commission approves projects only if they are just, reasonable, and in the public interest.
Siting rules and farm protections
Energy storage systems now count as supporting facilities for wind and solar sites. Project owners must file a farmland drainage plan and restore surface and underground drainage during and after construction. Owners must pay for crop losses and fix or pay to fix any drainage system damage they cause.
Funding priorities for energy transition programs
The law sets yearly caps and order of spending for many clean‑energy workforce and community programs. Examples include $26.5 million a year for the Clean Jobs Workforce Network after 2026, up to $41 million a year for Jobs and Environmental Justice grants, and up to $40 million a year for community support grants. It also caps the annual energy transition assistance charge and directs any year‑end surplus to items like Stretch Energy Codes ($500,000), efficiency and Clean Air Act funds ($7 million), and State fleet electrification ($10 million).
Up to 80% rebates for EV chargers
Beginning July 1, 2022, the Illinois Power Agency gives rebates or grants for Level 2 or Level 3 EV chargers while funds last. Awards can cover up to 80% of installation costs, with extra per‑port help in eligible communities and for eligible persons. Applicants must agree to pay the prevailing wage. The Agency must act within 60 days of each application. This section is repealed on January 1, 2029.
Cap on utility efficiency evaluation spending
Each year, an independent review checks how cost‑effective a utility’s efficiency programs are. Spending on that review cannot be more than 3% of the year’s program budget. This helps keep most money going to actual energy‑saving measures.
Regulators must weigh customer costs
When reviewing certain utility construction or transactions, the Commission must give primary weight to customer costs or savings. It may still consider other factors. This change puts customer bill impacts first in those decisions.
Solar for homes, schools, communities
The Adjustable Block Program buys RECs from new solar projects energized on or after June 1, 2017. The program sets minimum shares: 20% small systems (25 kW or less), 20% mid‑size (over 25 kW up to 5,000 kW), 30% community solar, 15% on public school land, 5% community‑driven community solar, and 10% from equity‑eligible contractors. If approvals exceed current collections, the Agency may reserve future uncommitted funds on a first‑come basis to hold your place.
State plan to expand renewables
The Commission creates a Renewable Energy Access Plan to guide transmission and projects. It adopted the first plan by December 31, 2022 after hiring experts and taking 120 days of public comments. Updates are required by December 31, 2025, again within 180 days of the new law, and then every other year starting in 2028. The plan must name renewable zones, map needed transmission, consider options like hydropower conversions, and, when evidence supports it, be approved to meet clean energy goals. After final recommendations, the Commission notifies regional grid operators and utilities.
Utilities can hire grid management providers
Utilities may contract third‑party providers to manage distributed energy resources. Programs should not be delayed because a utility lacks these systems. This helps speed up virtual power plant and grid services.
Utility grid upgrades and studies
Large transmission‑owning utilities may plan where to add advanced transmission tech to boost resilience, reduce curtailment, and connect renewables. They may also study where the grid has unused capacity (headroom) and list interconnection points and megawatts. The Commission set up a Division of Integrated Distribution Planning with at least 13 staff by January 1, 2022 to support this work.
Coal‑to‑solar fund can’t be swept
The Coal to Solar and Energy Storage Initiative Fund is protected from sweeps, chargebacks, and other transfers. Money in the fund stays available for its programs.
No state buys from labor violators
Beginning January 1, 2022, the Agency cannot buy goods or services from entities that violate the Displaced Energy Workers Bill of Rights or fail to meet set labor standards. This ties state purchases to labor compliance.
Loans for thermal energy networks
The Illinois Finance Authority may run a Thermal Energy Network loan and assistance program, if funding is available. It can make loans and grants for community‑scale projects like geothermal, set rules and fees, coordinate with the Commission on pilots, and recycle repayments into new projects.
Energy transition charge on your bill
If your utility serves more than 500,000 customers, it adds a uniform cents‑per‑kWh Energy Transition Assistance Charge. The charge is capped at 1.3% of the 2009 per‑kWh amount, and the cap rises by 0.636 percentage points on January 1, 2028. Tariffs were filed within 75 days and began no later than the first billing cycle on or after January 1, 2022, with annual updates. Utilities must send collections to the Department of Revenue by the 20th of the next month, and you cannot be disconnected just for not paying this charge. The Department sets each utility’s annual charge within statutory caps, up to $84.8 million a year shifts to the Electric Vehicle and Charging Fund starting January 1, 2028, and agencies may use limited amounts for administration.
States share some radioactive waste costs
If post‑closure care costs exceed the Fund or insurance, each Compact state with waste generators pays its share based on the volume it sent. A state is exempt if its annual volume is under 10% of the region’s total that year. The state Agency can also accept donations of money or goods for these purposes, and money goes into the Low‑Level Radioactive Waste Facility Fund.
Nuclear projects: fees and rules
For any reactor that starts operating after January 1, 2026, the owner pays a one‑time fee. It is $1.5 million for a new site with an emergency planning zone, $600,000 for a new site without that zone, and $500,000 for a reactor at an existing site with a pre‑2026 unit. The Agency also has authority to make rules needed to carry out the nuclear safety law.
Smaller cap for community projects
The maximum size for a community renewable project is now 5,000 kilowatts. The old limit was 10,000 kilowatts. Projects may be smaller and may serve fewer subscribers.
Mixed changes to rooftop solar bills
Beginning January 1, 2025, new net metering applicants use the new subsection (n); systems registered before then stay on the older rules for their lifetime. If your distributed generation rebate is approved, you stop getting delivery credits for excess power, unless the rebate was only for an energy storage device. For on‑bill financing, the initial per‑site loan cap is $150,000 and is later replaced so the required monthly payment is no more than 50% of your average monthly utility bill.
On-bill financing for energy upgrades
Large utilities must offer on‑bill financing so homeowners and small businesses can buy approved efficiency measures with no upfront payment and repay on the bill. The total outstanding loans per utility start at $2.5 million and rise by $5 million each year after the 99th General Assembly’s effective date until reaching $20 million. Utilities recover start‑up and program costs from residential and small commercial classes through an automatic adjustment charge. The utility sends monthly payments to lenders and, if a customer defaults, may recover costs through the tariff, keep a security interest in financed equipment, and disconnect service.
Stronger rights for home solar and batteries
Customers of co‑ops and city utilities can install on‑site renewables and storage to power their own use. Homes and small businesses can interconnect systems up to 25 kW AC, and utilities must connect you promptly under safety rules. Your export credit matches your provider’s hourly time‑of‑use price. Utilities cannot use unfair rates, extra fees, or insurance add‑ons if your installer carries at least $1,000,000 per incident and $2,000,000 per year. If your old meter cannot measure two‑way flow, you must pay for a bi‑directional meter. Utilities must also remove rules that block charging batteries from the grid or exporting from storage.
Limits and credits on utility surcharges
Electric utilities can cancel an automatic adjustment tariff, then seek cost recovery through a new tariff or next rate case. The Commission has 75 days to act on the new tariff, and any over‑collection must be credited once to customer bills. Gas utilities can recover efficiency costs through a special tariff, with yearly true‑ups. The law caps average bill impacts from efficiency: electric plans have percentage caps by cycle, and gas plans have a 2% cap per multi‑year period. State policy also allows utilities to recover prudent efficiency costs.
New time-of-use electric rates
Your utility must offer time-of-use plans within 120 days of the law taking effect, with at least three time blocks. Prices use regional PJM/MISO averages and include day‑ahead price info. These rates include capacity and transmission costs; charges can change monthly and time blocks yearly with at least two weeks’ notice. The utility buys power day‑ahead and passes supply costs through a purchased energy adjustment. The Commission must finish time‑of‑use tariff reviews within 240 days.
Thermal pilot protections and cost recovery
For Commission‑approved thermal energy network pilots, the Commission can approve rebates, incentives, and special tariffs. It only approves rates if your projected heating and cooling costs are no higher than without joining, while weighing comfort and safety. Utilities can recover authorized pilot costs through Commission‑approved tariffs. If authorized funds remain unrecovered by January 1, 2029, the EPA allocates the remainder to the Illinois Finance Authority for beneficial electrification programs.
Utility efficiency charges true‑up
Utilities must compare last year’s energy‑efficiency revenue requirement to actual costs. If they collected too much, customers get a credit; if too little, customers pay the difference, with interest at the utility’s approved cost of capital. Interest excludes deferred taxes and includes a factor for income taxes. Since June 1, 2017, utilities may defer efficiency spending as a regulatory asset, spread costs over the measures’ average life, and earn a return on the unpaid balance.
Virtual power plant rules and payments
By June 30, 2026, the state sets up a scheduled‑dispatch virtual power plant. If you own storage and got a rebate, you must enroll for five years. Summer weekday dispatch is 4–6 p.m. for behind‑the‑meter systems and 4–7 p.m. on the distribution system; the Commission can allow other schedules within limits, and there are no penalties for non‑performance. Batteries, EVs, and other devices can enroll through aggregators; low‑to‑moderate income customers and community projects get higher upfront payments, and performance payments are fixed for five years with an option to reenroll. Utilities can recover program costs through tariffs, and large utilities must file VPP tariffs by December 31, 2027; at least one must be approved by December 31, 2028.
Utilities fund efficiency and recover costs
Very large utilities must fund at least $25,000,000 a year for third‑party efficiency programs; mid‑size utilities must fund at least $8,350,000. Utilities must run competitive solicitations with independent scoring and rank bids by cost per lifetime kWh saved. Each plan must include a tariff to collect program costs from customers so approved costs are recovered. Missing the filing deadline costs a utility $100,000 per day until filed. The law also targets a 0.1% yearly cut in peak demand for eligible customers through December 31, 2026.
Pay, training, and diversity on transmission work
Starting February 20, 2025, utilities and contractors must pay prevailing wages and benefits on electric transmission work. Workers must be qualified through an accredited apprenticeship (completed or enrolled with completion) or have at least 2 years of direct experience, and must complete OSHA‑certified safety training for their roles. Contractors must file a Diversity Plan showing apprenticeship and work‑hour goals for minorities and women and report prior‑year spending with targeted businesses.
How storage property is taxed
Starting in assessment year 2026 through 2040, commercial energy storage systems use a set formula for property taxes. The cost basis is $65 per kWh, trended (stand‑alone: lesser of 2% or a CPI number; tied to generation: 1.00). Physical depreciation equals age/25 of the trended basis, with a floor so assessed value stays at least 30% of the trended basis. You may also get up to a 70% reduction for proven functional or external obsolescence. Owners must pay the real estate taxes and must provide a metes‑and‑bounds survey; without a survey, the county sets the site area and that decision is final. Systems under this Division are exempt from equalization factors, districts may vote to abate taxes, and Cook County is excluded.
Stronger labor rules for storage and pilots
Energy storage projects must follow prevailing wage and project labor agreement rules. Storage facility operators must keep a labor peace agreement with a bona fide union to operate. Contractors on thermal energy network pilots must be responsible bidders, pay prevailing wage, submit proof, and have a project labor agreement before construction. Pilot operators must also maintain a labor peace agreement.
Installer and wage rules for solar bids
RECs from new solar in the supplemental procurement must be installed by a qualified person. That includes journeyman electricians, supervised apprentices, or workers with listed credentials and 5 years or 8,000 hours of hands‑on electrical work. To win an award, firms must certify they pay at least the state prevailing wage. REC contracts for distributed generation run at least five years. The Agency may also charge bidder fees to cover procurement costs.
New rules to bid on storage
Storage buys must solicit 20‑year contracts, while plans also consider other terms, durations, stand‑alone or integrated storage, and how to split capacity across regions. Bidders face new costs and gates: a nonrefundable deposit of at least $10,000 per bid, Agency fees and possible collateral, and a requirement to show past projects totaling at least 100 megawatts at notice‑to‑proceed. The Agency must coordinate with MISO and PJM interconnection queues, set confidential price benchmarks, and send winning bids to the Commission for approval. Winners must show an interconnection agreement before any storage credit payment. Contracts also protect sellers: if a utility’s cost recovery remains authorized, sellers get full and prompt payment under the contract.
Supplier diversity plans and enforcement
Projects must set supplier diversity goals and file a DEI plan within 60 days of approval or grant signing. At least 25% of eligible contract spending must go to listed diverse suppliers, with limited exclusions. Awardees must file yearly progress reports and a final report on the fifth June 1 after commercial operation, plus follow a yearly compliance plan, midyear confirmation, and year‑end report. If an entity fails the minimum equity standard, the Agency can bar it from procurements, require a corrective plan, and allow reapplication after compliance.
Rules for sharing utility usage data
Within 90 days, the Commission must start rulemaking to set how utilities share customer usage data. Utilities are not liable if a third party misuses shared data, unless the utility broke the rules or was grossly negligent. Utilities can ask to recover reasonable data‑sharing costs but must subtract any outside funding from future rate requests. The Commission can hire consultants for this work using an exempt process. Large utilities must also report total kWh delivered each year, with an initial report shortly after the 2021 law change and then by October 31 each year.
Limits on large reactors; SMR defined
No new nuclear reactor larger than 300 megawatts may start construction unless the U.S. approves a waste‑disposal technology or the legislature specifically allows it. The law defines a small modular reactor (SMR) as an advanced reactor of 300 MW or less, which can be built with similar units at one site.
Small nuclear reactors allowed starting 2026
Starting January 1, 2026, construction may begin on new nuclear reactors up to 300 megawatts if the builder gets all required permits and approvals, funds decommissioning, and meets federal and state rules.
Yearly emissions reports and reliability backstop
Starting June 30, 2025, the Illinois EPA posts yearly greenhouse gas emissions by unit and statewide for the prior year. Every five years starting in 2025, three agencies issue a public report on clean energy progress and grid reliability by December 15. If they find a resource shortfall, they must create a mitigation plan that can delay or reduce emissions cuts only as needed to keep the grid reliable. The plan includes a public workshop, 60 days of comments, and Commission approval.
Setbacks and owner waivers for wind/solar
Wind projects must meet setback rules based on blade‑tip height and limit shadow flicker at homes and community buildings to 30 hours per year. Solar projects must meet 150‑foot and 50‑foot setbacks, have 6‑ to 25‑foot fencing, and panels under 20 feet at full tilt. Owners of nearby nonparticipating properties can waive certain siting protections with written consent. Property owners may also record a waiver of certain noise rules, which binds future owners and must be disclosed to buyers and lessees.
Faster siting approvals and disputes
If your project meets the law, the county must approve siting and you get at least 3 years to start work or get a building permit. A development permit expires after 2 years if you do not start, but the clock pauses during formal reviews or court delays. Owners may file an expedited complaint; the Commission moves cases on short deadlines and can issue a siting certificate or seek court orders. Parties must pay the Commission’s proceeding costs. Road‑use deals must make the owner pay reasonable road improvements and repairs tied to construction, but not unrelated work or extra fines.
Setbacks for wind and solar projects
Counties must keep commercial wind towers back 2.1 times blade‑tip height from nonparticipating homes and occupied community buildings, and 1.1 times from participating homes and some lines. Wind projects must show shadow flicker at those buildings is 30 hours per year or less. For commercial solar, panels must be 150 feet from homes and occupied community buildings and 50 feet from roads and property lines. Fences must be 6–25 feet high, and no panel may exceed 20 feet at full tilt.
Statewide siting and safety for storage
Counties can require commissioning reports, hazard and emergency plans, and warning signs. Batteries must meet UL 1973 and UL 9540 listings, and owners can be required to train local responders. Counties cannot ban storage in zones that allow farming or industrial uses, and cannot set noise limits stricter than state rules. Owners may upgrade to keep original capacity without new local permits. A county may charge one building permit fee, capped at the lesser of $5,000 per MW or $50,000. Prior applications filed before the law are grandfathered. Counties also cannot require property value guarantees or devaluation escrow payments.
Uniform rules for big battery projects
An energy storage project is covered if it is over 1,000 kilowatts. Counties with zoning may set rules, but they cannot be stricter than the state standards. Storage sites must be 150 feet from homes and occupied community buildings, and 50 feet from property lines and roads. Perimeter fences must be 7–25 feet tall. Projects still must meet electrical and safety clearances.
Charge funds storage at coal sites
Large utilities must buy RECs from new renewable and storage projects built at or near former coal plant sites. By July 1, 2022 they filed a tariff for the Coal to Solar and Energy Storage Initiative Charge, which takes effect January 1, 2023. The charge pays for contracted RECs and funds grants for storage at eligible sites through a new state fund.
Clean energy REC contracts and rules
The state buys renewable energy credits (RECs) through long‑term, indexed contracts. Each month, payments equal the market index price minus the strike price, times RECs produced; contracts last at least 20 years. Utilities must take shares of REC purchases based on their 2021 delivery volumes. Certain HVDC‑delivered resources count as in‑state if they meet five conditions, including 525 kV capability and energizing after June 1, 2023. Geothermal RECs must use a set MWh formula, and systems with costs recovered in regulated rates after the law’s effective date are not eligible. The Agency can plan for carbon‑mitigation credit buys starting June 1, 2022 and earlier ran initial procurements in 2017 for 1,000,000 RECs per year starting in 2019.
Energy procurement and siting rules updated
The Agency now uses a long‑term renewable resources plan instead of annual plans (starting with the 2017 delivery year). It can also prepare procurement plans for small multi‑state utilities that served fewer than 100,000 Illinois customers in 2005, if they ask. When a municipal power agency seeks eminent domain for a new plant, the Commission must consider whether that plant fits the agency’s latest preferred IRP portfolio or least‑cost plan. For storage procurements, alternative contract types are allowed only if utilities can fully and promptly recover costs, face no financial harm, and agree to the terms.
Energy Transition Assistance Fund created
The state creates the Energy Transition Assistance Fund. It holds money collected under this law. The Department of Commerce and Economic Opportunity can spend it for the law’s purposes when the legislature approves the spending.
Faster, price-based power buying rules
Power purchases use sealed, pay‑as‑bid RFPs chosen on price, with standard contracts. A procurement administrator runs the process and a monitor reviews it. After bids open, confidential reports go to the Commission within two business days, and the Commission decides within two more days. Utilities must sign contracts within three business days after approval. Winners’ names and average winning prices are public, while other bid details stay confidential. If a supplier defaults on 200 MW or more with over 60 days left, a new procurement runs; otherwise, the utility buys from the regional market. If a procurement fails, officials meet within 10 days and can run a new RFP within 90 days. These procurements are exempt from the Illinois Procurement Code.
Gas utilities can boost efficiency spending
Gas utilities file four‑year efficiency plans and can ask to spend above caps starting with plans filed by March 1, 2026 for 2027–2029. To qualify for incentives, a plan must budget at least 5% of amounts paid by non‑opt‑out customers, show at least 0.7% average yearly savings, and an average savings life of at least 12 years. Plans repeat every four years and must coordinate with electric programs and focus on income‑qualified savings.
New clean energy buys at coal sites
Large utilities (over 300,000 customers on January 1, 2019) must buy renewable credits from new solar plus storage at sites that burned coal as of January 1, 2016. They must also buy storage credits or services for energy storage resources. The Agency also sets up plans to buy carbon mitigation credits from carbon‑free resources for eligible customers. These targeted buys support clean energy at former coal sites and storage, and may affect rates.
REC payments protected; utilities recover costs
If a rate cap would block full payment under an existing REC contract, the utility must still pay the seller in full. It must first use unspent funds in an interest‑bearing account. If that is not enough, the utility still pays now and may recover the rest later through future collections. The Agency must notify the Commission and may pause or reduce new awards while it decides.
State sets higher renewable credit targets
The law sets clear goals for clean energy credits. It aims for at least 13% by the 2017 delivery year, 25% by 2025, and 40% by 2030, with a goal to try for 50% by 2040. It grows annual REC deliveries from 10 million by 2021 to 45 million by 2030, with about 45% from new or repowered wind and hydropower and at least 55% from solar. New wind and solar must be energized after June 1, 2017; RECs from contracts before June 1, 2021 cannot count toward new-project shares from 2021 on. Geothermal RECs are added through a new homes and businesses program. Purchases must be cost‑effective and stay within rate‑impact budgets and benchmark prices.
4% cap on efficiency R&D spend
No more than 4% of energy‑efficiency and demand‑response program revenue may fund research and pilot projects. Utilities must work with stakeholders and file a four‑year plan. If a utility asks to change its annual savings goals, it cannot spend portfolio dollars on R&D proposals.
New fees and funds for nuclear waste
Small modular reactors must pay the same low‑level radioactive waste fees as other covered reactors. Reactor owners pay the lower of the Section 13(a) fee or $30,000 per reactor each year, and the Agency may add up to another $30,000 per reactor if the Fund balance is under $500,000 at year‑end after notice and hearing. The law creates two State funds to pay for operations, decommissioning, monitoring, insurance, community agreements, and compensation, subject to appropriation. If waste acceptance is interrupted, the Agency can charge emergency fees due within 30 days. The Agency must set fee rules before a facility opens and can seek penalties up to $100,000 per day or up to four times unpaid fees.
New rules for energy storage
Storage credits are not allowed for systems whose costs are recovered through regulated utility rates on or after January 1, 2017. The law defines energy storage systems and excludes technologies that require combustion. In virtual power plant events, utilities cannot send dispatch signals directly to customers who have an aggregator; the aggregator stays the communications link.
New rules for renewable credits
RECs from a unit whose costs are recovered in regulated rates on or after January 1, 2017 do not count. If that happens, the contract can be ended and the supplier must return 110% of payments, which then buy new wind or solar RECs. Each MWh’s credits can be used only once, and then must be retired. Contracts for item (i) projects last 15 years with full payment at interconnection and the rest paid over six years; items (ii) and (v) get 15% upfront and the rest over six years. Items (iii) and (iv) use 20‑year contracts with annual payment caps based on generation, carryforwards, and prices tied to subscription, with 90% deemed fully subscribed. Utilities do not have to advance more than they reasonably expect to recover.
Nuclear waste fees and funds updated
The disposal facility must pay local ad valorem property taxes; other local taxes or fees are banned unless the Agency allows them. On or after July 1, 2025, the remaining Closure Fund balance moves to the Development and Operation Fund, and the Closure Fund is then dissolved. The minimum generator fee drops from $100 to $50 per year, or more if the per‑cubic‑foot calculation is higher; local governments and certain pre‑1980 reclamation shipments are exempt. Payments to local governments from the Nuclear Safety Emergency Preparedness Fund are capped at $650,000 per year.
Zero‑emission credit purchases end 2028
The Agency’s zero‑emission credit procurement authority ends on January 1, 2028. After that date, the Agency no longer buys ZECs under that part of the law.
Equity rules for clean energy contracts
Projects in Agency procurements must meet a Minimum Equity Standard, starting at 10% of the workforce and rising so the statewide average reaches 30% by 2030. Bid rules favor partnerships with equity‑eligible contractors and give preference to bids that send more contract dollars to them. The Agency is building a public database and online tool to find equity contractors, jobs, and funding. It will collect demographics on awardees and publish annual reports on compliance and waivers. The Agency may set prequalified supplier lists and use competitive bidding for construction contracts over $25,000.
Cap on renewable charge increases
The law limits how much renewable procurement can raise your bill. For the year starting June 1, 2026, the cap is 4.25% of what customers paid per kWh in the year ending May 31, 2009, adjusted for inflation. For the year starting June 1, 2027, the cap increases by 1.65 percentage points. The Agency reduces procurements to keep within these limits.
More rights and openness at co-ops
Co-ops must post bylaws, meeting schedules, agendas, approved minutes (within 30 days), and election rules on a public website. Members can address the board under new bylaws or policies. If your co-op or municipal utility violates self‑generation or storage rights, you can file a complaint under the Administrative Review Law. Within 180 days, co-ops and municipal utilities must update interconnection and fair‑crediting policies and post them online.
Net metering now allowed for storage
Energy storage and vehicle‑to‑grid systems of 5,000 kW or less that are energized after the law’s effective date can get net metering. Behind‑the‑meter storage must use hourly or time‑of‑use supply. Distribution‑level storage must take hourly supply service.
On‑bill financing opens to associations
Utilities must offer on‑bill financing to eligible Unit Owners’ and Master Associations that are residential or small commercial customers. Repayment cannot be set up through unit owners’ individual utility bills. Financed measures must be cost‑effective, or a certified auditor must find they are likely cost‑effective. Needed installation items are allowed if they are no more than 25% of the total installation cost.
Stronger protections for clean energy buyers
The Agency runs vendor registration with baseline qualifications and a public approved‑vendor list. It can require standard customer disclosures, inspections, and run a Consumer Complaints Center with public reports. Vendors may have to post security bonds to repay harmed customers. The Agency can also register financing companies, set consumer rules, and revoke bad actors. It may restrict REC pass‑through offers, require escrow or proof of customer payments, and still allow upfront discounts.
Cap on opt-out customer charges
If you opted out under subsection (l) of Section 8‑103B, the utility checks each April 30 through 2026 to see if your per‑kWh charge needs a reduction. Any reduction applies for the next delivery year starting June 1. Your annual average net increase is capped at 1.3% of 5.98¢/kWh (about $0.00078 per kWh).
Geothermal incentives with home set-asides
Beginning June 1, 2028, the Agency runs a Geothermal Homes and Businesses Program. It may spend up to $10 million per year to buy geothermal RECs using annual blocks and posted prices. At least 33% of each annual block is set aside for homes. The Agency aims for 40% of each block in equity‑eligible communities, and at least 10% for equity‑eligible contractors, with a plan to grow that share.
Existing solar contracts stay in place
Adjustable Block program contracts signed before new templates took effect do not have to change. Your original contract terms remain valid.
Past rules ended for some customers
The Section stopped applying to the customers described in subsection (m) after January 1, 2020. Any prior duties under that Section ended for that group.
No collateral for virtual power plant aggregators
Aggregators do not have to post collateral to join the virtual power plant program. The Commission may set other reasonable participation requirements.
Big gas customers can opt out
If a large private gas customer meets the demand rules and files a proper, timely request, the utility must grant an opt‑out. Starting January 1 of the next plan cycle, the customer is not charged for that cycle and cannot participate in it. The opt‑out lasts only for that one cycle. The utility must file the granted opt‑out with the Commission.
Faster permits and public transparency
The law speeds up permitting and keeps current rules in place while renewals are reviewed. If the Agency takes no final action in 90 days, you can treat the permit as issued; it is 180 days if public notice or a hearing is required. When a complete renewal is filed on time, the old permit’s terms stay in effect until a final decision. Coal-ash impoundment permits must include strong protections, and applicants must post application documents online and at a local office. Some complex federal permit types are excluded from the fast timelines.
Stronger control of radioactive waste
The Agency can block waste shipments that would break the Compact or this law and can require prior notice, disposal plans, time limits, bonds, and consent to service of process. Violations can bring civil penalties up to $100,000 per occurrence, recovery up to four times unpaid penalties, and Class 4 felony charges for intentional violations. Penalties go to the state fund, and the Attorney General enforces at the Agency’s request.
Tougher rules and penalties for radioactive waste
The state can require notice, final disposal location, time limits on holding out‑of‑state waste, bonds, and consent to service of process. Violations can face civil penalties up to $100,000 per occurrence, with up to four times that amount if unpaid, and intentional violations are Class 4 felonies. At the Agency’s request, the Attorney General must sue or prosecute. Civil penalties go to the Low‑Level Radioactive Waste Facility Fund.
Small utilities exempt from time‑of‑use
If your electric utility serves 100,000 or fewer customers, the time‑of‑use section does not apply. Those smaller utilities and their customers keep existing rate rules instead.
Faster contracting for Early Childhood
The Department of Early Childhood can skip certain procurement rules when needed to carry out the law. The purchases must be just for the Department and necessary and appropriate. Starting January 1, 2025, the Department reports quarterly to lawmakers on contracts using this exemption. This authority ends July 1, 2027.
Flexible buying for state employee recruiting
State agencies can bypass some procurement steps for recruiting and retention costs, like job fair fees and materials. The agency must decide in good faith the expense is necessary and follow set procurement guidance. This authority ends June 30, 2029.
Self-direct renewables for big users
Starting June 1, 2023, large customers with peak demand over 10,000 kW can self‑direct their renewable compliance. They must buy RECs from new utility‑scale wind or solar under contracts of at least 10 years equal to at least 40% of their annual use, and retire those RECs. The Commission reduces their volumetric charge each year using a method that reflects expected REC delivery costs, approved by June 1 each year.
Renewable energy fund created and used
The state created the Renewable Energy Resources Fund, run by the Illinois Power Agency. The fund buys renewable energy credits under plans the Agency approved before June 1, 2017.
Stronger utility planning and oversight
Every electric utility must file a five‑year procurement plan that shows hourly load, demand‑side and renewable programs, balancing, and how it will meet customer needs. The Agency hires qualified experts and a procurement administrator, with rules for credentials, conflict checks, objections within 5 business days, and contracts up to five years. The Commission reviews choices and can rule within tight timelines. Multi‑Year Integrated Grid Plan rules apply only to utilities with more than 500,000 customers.
Aggregators must receive utility signals
Aggregators in the virtual power plant program must be able to receive event signals from utilities or their DERMS providers. Firms may need to add or maintain communications tools to qualify.
Annual $20 fee for large fleets
If you register 10 or more covered vehicles in the Covered Area, you pay a $20 user fee per vehicle each fiscal year. Government, rental, antique, expanded‑use antique, electric vehicles, and motorcycles are exempt. The fee does not apply to vehicles under the International Registration Plan. The State deposits these fees into the Electric Vehicle and Charging Rebate Fund.
Program application fees for clean energy firms
The Agency can hire experts to run the Adjustable Block and Geothermal programs and charge application fees to participating firms. Fee levels come from the long‑term plan, and any change over 25% needs Commission approval. The Agency must minimize admin costs and can use fee proceeds for public education and coordination.
Nuclear plants must fund safety systems
Owners of nuclear reactors must provide the Agency with system status signals 24/7, including during accidents and recovery. The Agency sets which signals are required. Owners must install Agency‑purchased equipment at their plants and pay for any site changes and updates the Agency requests.
State charges utilities program fees
The Agency charges affected utilities fees to cover the costs of making procurement plans and running programs tied to each utility’s plan. The law does not set the fee amounts.
Limits on renewables fund deposits
After all payments required by Section 16‑115D are received, no more money goes into the Renewable Energy Resources Fund unless the Commission orders it. This can limit future funding for programs tied to that fund.
Dual‑meter rule for some generators
If certain net metering rules do not apply to your renewable system, the utility uses dual‑channel meters. You still pay taxes, fees, and delivery charges on gross kWh from the provider. The provider pays you monthly for extra kWh at avoided cost or as set in your power purchase agreement.
Environmental permit changes for businesses
A State surface mining permit does not replace local rules; you must still meet local siting and operating laws. The Agency cannot issue permits for sites in prohibited setback zones. Air permits are not required solely due to greenhouse gas emissions under Section 9.15.
Joint Lake Michigan dredging permits
For dredging or placing material in Lake Michigan, the Agency and the Department of Transportation issue a joint permit. Applicants follow the joint process set in state law.
Large energy users can opt out
Eligible large private energy customers can opt out of a utility’s multi‑year plan. The opt‑out starts on the next January 1 after notice. You stop being charged plan costs and cannot join that 4‑year plan cycle. Notice must be filed 12 months before the next cycle, with limited transition allowances.
More public notice for new landfills
New municipal solid waste landfills, or lateral expansions not already locally approved, must publish a county‑newspaper notice at least 15 days before filing. The Agency accepts public comments postmarked within 30 days after filing, unless extended. Applicants must also file a copy with the county board or city, excluding trade secrets, and local offices must make it available for public review.
Utilities check vendor equity quarterly
If you are a utility vendor or contractor, the utility must collect compliance data every quarter. It must report progress to you and provide training and resources to help you meet workforce equity rules. The utility may change or end work with vendors that do not assist with compliance.
Coal-to-solar grants and procurements set
The Agency runs two coal-to-solar procurement events. The first runs by March 31, 2022 (or May 1, 2022 if delayed) for projects south of I‑80. The second runs between Sept. 30 and Oct. 31, 2022 statewide. The Department accepted grant applications until March 31, 2022 and announced awards by June 1, 2022. The Agency can charge application and procurement fees. Grant contracts must be in writing and list the dates each year when payments will be made.
Faster, uniform county rules for storage
Counties can require energy storage sites to follow NFPA 855 safety rules and may not add stricter rules. A county must hold a public hearing and finish it within 60 days, then decide within 30 days. After operation starts, a county can require one perimeter sound test to show the site meets state noise rules. Counties must process building permits within 60 days or the permit is deemed granted. If a permit is denied, the county must state the reason in writing.
Simpler permits for compost sites
The Agency issues permits for landscape‑waste composting. Applications need a legal description, a detailed map, operations plan, volumes, and proof of setbacks, water‑table, dust, and odor controls. If denied, the Agency must send a detailed reason. If it takes no action in 90 days, the permit is deemed approved unless you waive that rule. Operators must file an annual tonnage report by April 1.
Nuclear definitions and oversight limits
The law defines small modular reactors as advanced nuclear units up to 300 MW that can share a site, adds Kentucky to the Region, and updates the agency name. It repeals Section 2.5 of the Nuclear Safety Preparedness Act. The Agency cannot run resident inspector programs at plants unless the law specifically allows it.
Tougher enforcement, some GHG permit relief
Agencies cannot grant exceptions to the emissions cuts set in law. You do not need an air permit solely for greenhouse gases if your source is not covered by federal or specified state GHG rules. The Illinois EPA can deny a permit if past site activities may have caused contamination unless that contamination is already allowed under an existing permit, and applicants must provide needed information.
Cleaner backup generators at data centers
Data centers filing certain air permits within six months must use diesel generators that meet at least EPA Tier 4‑level protections and natural gas units that meet at least EPA Tier 2‑level protections. Generators may run only for emergencies or standby. If a unit becomes non‑compliant during an outage, it may run up to 24 hours after that without a permit violation.
Transparency and secrecy in contracts
If a municipal power or gas agency discusses a contract in closed session, it must hold at least one public meeting before final approval. At the same time, confidential procurement reports and supplier bid details are not public or usable in court unless there is a compelling need, and then only for law enforcement.
Shift unused REC capacity to waitlists
If a REC program category has unused capacity at year end, the Agency moves it to other categories, prioritizing those with waitlists. The moved capacity is added to next year at next year’s price and does not count toward certain program goals. Over time, the Agency can grow item (vi) up to 40% by reducing items (i)–(v) to rebalance projects and avoid geographic concentration.
State inspectors at nuclear plants
The state places one full‑time Illinois resident inspector at each nuclear plant when the program is fully in place. Plant owners must provide office space and equipment at their expense. The law also defines small modular reactors as advanced reactors of 300 MW electric or less in both nuclear safety and low‑level waste laws. Inspectors work under a federal agreement and have the same access limits as NRC resident inspectors.
Limits on local solar rules and court fees
County and municipal solar Divisions do not apply to buildings over 60 feet or most shared roofs. They do apply if the system sits fully in one owner’s portion with agreement from all roof owners, or for specified low‑voltage devices. In lawsuits under these Divisions, the winning party can recover court costs and reasonable attorney fees.
Uniform county rules for wind and solar
Counties can set standards for commercial wind and solar, but not stricter than state rules. Before approval, counties must hold at least one public hearing that ends within 60 days of the application and decide within 30 days after the hearing. Facility owners must sign an agricultural impact mitigation agreement before the hearing. Counties may require environmental and historic site consultations and detailed site plans that show roads, lighting, screening, and zoning.
State rules shape local siting
High‑voltage lines now mean 100,000 volts or more. Counties cannot set wind or solar sound limits stricter than state rules, though parties can waive enforcement by written waiver. Counties with zoning that conflicts with this law must fix it within 120 days after the law takes effect.
Caps on EV rebate admin money
The state sets annual caps on administration from the Electric Vehicle and Charging Rebate Fund: up to $225,000 per year to the Agency through FY2023, up to $600,000 per year beginning in FY2024, and up to $225,000 to the Secretary of State. Money left after these caps goes to programs and can be spent only after it is collected and deposited.
Big utilities must warn before job cuts
Public utilities with over 100,000 customers as of January 1, 2025 must give the Commission 45 days’ notice before a substantial workforce change. A substantial change means cutting over 5% of total workers or dropping the labor‑spend‑to‑capital‑spend ratio by more than 5%. The notice must explain why, impacts on service quality and reliability, and how the utility will reduce hardship for affected workers.
Sponsors & Cosponsors
Sponsor
Steve Stadelman
Democratic • Senate
Cosponsors
Ann M. Williams
Democratic • House
Bill Cunningham
Democratic • Senate
Jay Hoffman
Democratic • House
Sara Feigenholtz
Democratic • Senate
Stephanie A. Kifowit
Democratic • House
Roll Call Votes
Senate vote • 10/30/2025
House Floor Amendment No. 5 Senate Concurs
Yes: 37 • No: 22
Senate vote • 10/30/2025
House Floor Amendment No. 4 Senate Concurs
Yes: 37 • No: 22
House vote • 10/29/2025
House Floor Amendment No. 5 Recommends Be Adopted Executive Committee;
Yes: 8 • No: 4
House vote • 10/29/2025
House Floor Amendment No. 4 Recommends Be Adopted Executive Committee;
Yes: 8 • No: 4
House vote • 10/29/2025
Third Reading - Short Debate - Passed
Yes: 70 • No: 37
House vote • 10/28/2025
Do Pass / Short Debate Executive Committee;
Yes: 8 • No: 2
House vote • 5/30/2025
Motion to Suspend Rule 21 - Prevailed
Yes: 76 • No: 39
Senate vote • 4/10/2025
Third Reading - Passed;
Yes: 54 • No: 0
Senate vote • 4/3/2025
Do Pass as Amended Public Health;
Yes: 10 • No: 0
Actions Timeline
Public Act . . . . . . . . . 104-0458
1/8/2026SenateEffective Date June 1, 2026
1/8/2026SenateGovernor Approved
1/8/2026SenateSent to the Governor
11/25/2025SenateAdded as Chief Co-Sponsor Sen. Bill Cunningham
11/7/2025SenatePassed Both Houses
10/30/2025SenateSenate Concurs
10/30/2025SenateHouse Floor Amendment No. 5 Senate Concurs 037-022-000
10/30/2025SenateHouse Floor Amendment No. 4 Senate Concurs 037-022-000
10/30/2025SenateHouse Floor Amendment No. 5 Motion to Concur Be Approved for Consideration Assignments
10/30/2025SenateHouse Floor Amendment No. 4 Motion to Concur Be Approved for Consideration Assignments
10/30/2025SenateHouse Floor Amendment No. 5 Motion to Concur Referred to Assignments
10/30/2025SenateHouse Floor Amendment No. 5 Motion to Concur Filed with Secretary Sen. Steve Stadelman
10/30/2025SenateHouse Floor Amendment No. 4 Motion to Concur Referred to Assignments
10/30/2025SenateHouse Floor Amendment No. 4 Motion to Concur Filed with Secretary Sen. Steve Stadelman
10/30/2025SenatePlaced on Calendar Order of Concurrence House Amendment(s) 4, 5 - October 30, 2025
10/30/2025SenateSecretary's Desk - Concurrence House Amendment(s) 4, 5
10/30/2025SenateChief Sponsor Changed to Sen. Steve Stadelman
10/29/2025SenateThird Reading - Short Debate - Passed 070-037-000
10/29/2025HousePlaced on Calendar Order of 3rd Reading - Short Debate
10/29/2025HouseHouse Floor Amendment No. 5 State Mandates Fiscal Note Requested as Amended - Withdrawn by Rep. Jay Hoffman
10/29/2025HouseHouse Floor Amendment No. 5 State Debt Impact Note Requested as Amended - Withdrawn by Rep. Jay Hoffman
10/29/2025HouseHouse Floor Amendment No. 5 Racial Impact Note Requested as Amended - Withdrawn by Rep. Jay Hoffman
10/29/2025HouseHouse Floor Amendment No. 5 Pension Note Requested as Amended - Withdrawn by Rep. Jay Hoffman
10/29/2025HouseHouse Floor Amendment No. 5 Land Conveyance Appraisal Note Requested as Amended - Withdrawn by Rep. Jay Hoffman
10/29/2025House
Bill Text
Engrossed
Enrolled
House Amendment 1
House Amendment 2
House Amendment 3
House Amendment 4
House Amendment 5
Introduced
Senate Amendment 1