All Roll Calls
Yes: 385 • No: 82
Sponsored By: G. Murrell Smith, Jr. (Republican)
Signed by Governor
Electrical Utilities
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26 provisions identified: 13 benefits, 2 costs, 11 mixed.
Large utilities must run at least biennial, competitive procurements for renewables and co‑located storage, with resources intended in service by January 1, 2035. Procurements need an independent evaluator, public notice 90 days before bids, contracts and methods posted 45 days before, and a public report within 60 days of awards. The PSC must open a docket within six months to set a storage procurement program. Utilities file details within 12 months, and small, local storage (≤20 MW) for reliability is exempt. Procurements should balance utility and third‑party ownership. Costs for third‑party‑owned storage may go into the utility’s rate base, and the law lets utilities defer reasonable implementation costs for PSC review and possible recovery later.
New power plants larger than 250 megawatts cannot be added to customer rates automatically. The utility must use a full rate case or a special prudence hearing to recover those costs. This does not stop recovery of a return on construction work in progress when allowed by law.
A residential customer‑generator can install up to 20 kW AC. A nonresidential customer is capped at the lesser of 1,000 kW AC or 100% of contract demand. Starting June 1, 2025, that nonresidential cap can increase to the lesser of 5,000 kW AC or 100% of contract demand if the customer is on a time‑of‑use rate and excess energy is credited and reset monthly. Larger than 5,000 kW AC is allowed if the customer and utility agree and the PSC approves. An energy storage device that charges only from onsite renewables also counts as a customer‑generator.
The PSC must open and complete avoided‑cost dockets, contracts, and forms within six months and review them at least every 24 months. Small power producers can lock in pricing by filing a notice of commitment and do not have to sign a PPA before a final interconnection if that risks their price. Utilities must offer 10‑year fixed‑price PPAs to qualifying facilities that had active interconnection requests before this law. Once executed interconnections and PPAs reach 20% of the utility’s five‑year average SC retail peak load, the PSC can require more fixed‑price offers. The PSC hires independent consultants, requires transparent filings, and updates methods to reflect energy, capacity, ancillary services, storage impacts, and location.
You can speak at PSC public hearings as a public witness without being a formal party. Cases now use written, prefiled testimony and finish discovery at least 10 days before the hearing. Intervenors pay their own costs, but the PSC can require utilities to share software if the intervenor reimburses the cost. Private briefings and site tours are allowed only with strict notices, ORS attendance, public posting of materials, and certifications. Willful illegal private contacts can lead to fines, removal, or firing. You have 30 days to petition for PSC review of an initial order and get an evidentiary hearing. PSC members’ pay equals 90% of a state Supreme Court associate justice and they must work full time. PSC-hired consultants must rely only on evidence in the record and cannot be a party.
Replacing a plant with a similar “like facility” is not a new major project; the commission must decide that request in 60 days, and any early site work is at the applicant’s risk. Applicants must compare their project to other options on cost, reliability, fuel, schedule, and more. ORS can file an independent evaluator’s report on the bidding and costs. Utilities can seek certificates for out‑of‑state plants in the same balancing area, but South Carolina customers cannot be charged if the commission denies the project and it proceeds anyway. Applicants must serve ORS and local officials and publish public notice. Hearings are set 60–90 days after a complete filing; the order is due within 180 days. Party and limited‑appearance rules are clarified. The Public Service Authority must prove builds and major deals are the most cost‑effective and lower risk, and needs approval for acquisitions and most contracts longer than 10 years (renewable buys from approved procurements are exempt). This review article ends 10 years after it takes effect unless renewed.
Each utility must file a voluntary renewable program within 120 days, unless it already has one that meets the law by July 1, 2025. Customers can pick the renewable facility and negotiate price under the approved form. All participants use equal‑length contracts and pay monthly for supplier costs plus an administrative fee. Programs can use utility‑owned or third‑party projects within the utility’s balancing authority and must support behind‑the‑meter options.
The commission must fully weigh economic development benefits and approve or deny negotiated rate deals within 60 days. For “transformational” customers, it must also find the deal has clear economic value and avoids cross‑subsidies. Starting May 12, 2025, utilities are protected in rate cases from having extra revenue “imputed” because they signed these deals. From May 12, 2025, directly competing existing customers can get similar special rates at the same time, if they prove they sell the same end product to the same customers.
State agencies must fast‑track energy project applications. You must hold a pre‑application meeting. Agencies have 30 days to check completeness, 15 days for you to fix gaps, and six months to decide. If they do not act in six months, the application is approved. Extensions must be in writing with a firm end date. You can appeal to the Administrative Law Court, which must issue a final order within one year unless extended for good cause. Any energy permit appeal still open on May 12, 2025 moves to the South Carolina Supreme Court.
The law defines who can get economic‑development power deals. Qualifying customers include very large users or locating/expanding firms that meet size, jobs, and investment tests. Transformational customers must add at least 50 MW, create 500 jobs, and invest $100 million with a Commerce designation. Contracts can last up to 10 years. Rates for qualifying customers cannot be below the utility’s marginal cost; transformational customers can get rates down to 75% of marginal cost. Utilities may also file co‑location agreements for resources on a customer site if the customer’s load exceeds 25 MW. The PSC reviews these filings quickly and can approve deals that protect other ratepayers.
In counties without rural solar zoning, large solar projects over 13 acres approved on or after January 1, 2026 must meet strict rules. Key rules include 50‑foot property setbacks; 200‑foot setbacks from the nearest home, church, or school; a 15‑foot panel height cap; two‑row vegetative screening planted 8–10 feet on center that hits 6 feet within three years; shielded lighting; at least 6‑foot fencing; anti‑reflective collectors; and an updated decommissioning plan. Counties must hold a hearing and give mail and newspaper notice at least 30 days before approval. The Department of Environmental Services can fine $100 to $5,000 per day for violations and may waive for good cause.
Electric companies can opt into annual rate reviews tied to what they actually earn. The commission sets an equity band that is plus or minus 0.50 percentage points around the last approved return. Utilities must file detailed quarterly reports and a year-end check. Each spring, the case moves on a set timeline: report by March 15, notice by March 31, interventions by May 15, audit and comments by June 1, company reply by June 15, and an Initial Order by July 15. Approved changes start with the first August bills. A final order by December 31 sets any refunds or surcharges, with corrected rates and credits or charges effective as of the first May billing cycle.
The commission requires cost‑effective energy‑savings plans and can appoint a third party to run low‑income programs if a large utility falls short. Utilities can propose incentives for rooftop solar, batteries, heat pumps, and other customer‑sited tools. The commission reviews these plans every three years and can change budgets. Large utilities must file yearly results. Small programs with under $5 million per year in incentives get faster review. The State Energy Office will publish plain‑English guides and a list of approved vendors.
Your utility can finance energy‑saving work and add a meter conservation charge to your bill. Not paying that charge can lead to disconnection under normal rules. Interest is fixed and capped: no more than 4 percentage points above the one‑year Treasury rate, and for regulated electric utilities, not above the utility’s last approved weighted average of equity and long‑term debt. You can prepay at any time with no penalty. A certified audit is required before work, and a certified inspection after. If a notice is recorded, future buyers can see the charge and the utility may keep billing them; the notice is not a lien. Utilities can recover reasonable setup costs in base rates.
The commission can approve energy‑saving programs for low‑income customers even if a single program is not cost‑effective, as long as the full portfolio is. Utilities can recover net lost revenues tied to customer‑sited solar or storage installed because of program incentives. Utilities and their contractors are not liable or warranting third‑party installation work. Contracts made for these upgrades are not covered by the state Consumer Protection Code. These on‑bill financing upgrades apply only in homes already occupied before the work. You generally cannot swap electric for gas (or gas for electric) using this section unless the same provider serves both fuels, or the new electric unit also runs on a backup fuel. For rentals, an energy audit is given when the lease starts, and a meter conservation charge can be used if both sides agree; if a landlord fails to notify the next tenant in writing, that tenant can deduct the charge from rent for up to half the lease term. Programs must show results for four cost tests, and a program or portfolio counts as cost‑effective if it passes at least two.
The commission can find that plans to pursue long‑lead clean power, like nuclear, advanced nuclear, biomass, hydrogen‑ready plants, or fusion, are in the public interest. It must balance jobs and industry retention, capacity and reliability, resource diversity, and the risks, costs, and benefits to ratepayers, and follow all laws. ORS and the Public Service Authority board apply the same standards.
Utilities and the Public Service Authority are encouraged to evaluate fusion and advanced nuclear. They must provide annual progress reports. If the PSC finds study and development costs reasonable and in the public interest, those costs may be recovered in rates. By December 31, 2027, they must report on small modular reactor options, including costs, timelines, co‑ownership, and federal benefits. The Governor’s Nuclear Advisory Council is created to guide strategy. If any such project is approved, ORS must monitor it and give monthly updates to the PSC and lawmakers.
The commission now emails or mails final orders, and they take effect when served. When a utility files a tariff, it must send a copy the same day to the Office of Regulatory Staff (ORS). In ex parte complaint cases, a judge can pause deadlines only if verified facts show the case was unfair, and must decide within 60 days. You have 15 days to seek rehearing, 15 days to respond, and the commission must issue a final order within 30 days after the response. Final merit orders can be appealed right away to the South Carolina Supreme Court. Starting May 12, 2025, ORS must consider commission requirements when it negotiates settlements. Reviews of Initial Orders are limited to compliance issues, but full rate cases can still be started.
Each utility and the Public Service Authority must file a yearly update to its resource plan. ORS reviews each update within 90 days, and the PSC can accept it or order changes within 60 days after the ORS report. ORS must also study who should run utility efficiency and demand‑side programs for large utilities. ORS starts within one year of funding and finishes the study in six months, then reports to lawmakers and the PSC.
The Office of Regulatory Staff will develop a 10‑year state energy assessment and action plan using utility resource plans and stakeholder input. For any project budgeted at $500 million or more, ORS must hire an independent construction analyst and get quarterly reports. Dominion Energy must study converting the Wateree plant from coal to biomass and report by January 13, 2026.
All utilities must file an integrated resource plan at least every three years and post it online. Plans must include 20‑year cost comparisons, demand forecasts, storage and renewables, and a detailed transmission report. The Public Service Commission reviews each plan within 300 days and approves, modifies, or denies it. The Public Service Authority must run a public stakeholder process, analyze self‑build versus alternatives, and include a portfolio that closes Winyah by 2028 and targets net‑zero by 2050.
The Office of Regulatory Staff (ORS) can add up to two positions per Article 24 utility to monitor these new rate rules. Utilities must pay for these positions. Each year, the Department of Revenue assesses an equal share to utilities by July 1, due July 15. Five years after May 12, 2025, ORS must file a full report on how Article 24 worked and may hire an outside expert. Report costs may be covered by assessments based on 25% of utilities’ in‑state gross revenues, as set out in law. Utilities may seek to recover these costs in rates.
Utilities cannot use LIHEAP or Weatherization dollars to fund their loan programs. Low‑income households can still receive LIHEAP or Weatherization help from local agencies. This protects federal aid but removes those funds as a source for utility‑run loans.
Starting May 12, 2025, a utility can share draft rate offers with the state Commerce Department or a prospective qualifying or transformational customer to attract investment and jobs. If a customer signs a deal and then leaves South Carolina or shuts down during the 10‑year term, it must repay the gap between standard rates and the discounted rates it paid. If the customer builds on‑site renewable generation, the project must follow all laws and codes. The utility may speed up interconnection when it does not harm reliable service.
Replacing older plants or lines can move faster when a project is a “like facility.” For generation, non‑nuclear projects up to 300 megawatts that replace capacity at the same site qualify. For transmission, rebuilds or upgrades within a right‑of‑way or on customer or state property can qualify. Applicants may, but do not have to, run an RFP to compare options.
The law encourages major utilities to study joint resources, more storage (including pumped hydro), hydrogen‑ready gas plants, and using South Carolina wood where appropriate. The Public Service Authority may jointly own new gas‑fired plants and related transmission near the former Canadys site with Dominion. PSA’s share matches what it contributes and it is liable only for its share. These steps can lead to future projects that the PSC reviews and that could affect bills later.
G. Murrell Smith, Jr.
Republican • House
Carl L. Anderson
Democrat • House
Lucas Atkinson
Republican • House
Brandon Newton
Republican • House
Cody T. Mitchell
Republican • House
Donald G. "Don" Chapman
Republican • House
Cally R. "Cal" Forrest, Jr.
Republican • House
Gil Gatch
Republican • House
Jerry N. Govan, Jr.
Democrat • House
Kevin Hardee
Republican • House
William G. "Bill" Herbkersman
Republican • House
Lee Hewitt
Republican • House
William M. "Bill" Hixon
Republican • House
Roger K. Kirby
Democrat • House
Thomas R. "Randy" Ligon
Republican • House
Steven Wayne Long
Republican • House
Marvin "Mark" Smith
Republican • House
W. Scott Montgomery IV
Republican • House
Thomas E. "Tommy" Pope
Republican • House
Robby Robbins
Republican • House
Carla M. Schuessler
Republican • House
Bill Taylor
Republican • House
Wm. Weston J. Newton
Republican • House
J. David Weeks
Democrat • House
Robert Q. Williams
Democrat • House
Mark N. Willis
Republican • House
Chris Wooten
Republican • House
Richard L. "Richie" Yow
Republican • House
All Roll Calls
Yes: 385 • No: 82
Senate vote • 5/7/2025
(Electrical Utilities)to concur
Yes: 35 • No: 11
Senate vote • 5/6/2025
(Electrical Utilities)Rule 32A waive printing
Yes: 44 • No: 1
House vote • 5/1/2025
(Electrical Utilities)Adopt Amendment 1a Amendment number 1a
Yes: 88 • No: 13 • Other: 1
Senate vote • 4/3/2025
(Electrical Utilities)3rd Reading
Yes: 38 • No: 3
Senate vote • 4/2/2025
(Electrical Utilities)to lay on the table Amendment number 20B
Yes: 32 • No: 11
Senate vote • 4/2/2025
(Electrical Utilities)2nd Reading
Yes: 41 • No: 3
Senate vote • 4/1/2025
(Electrical Utilities)to lay on the table Amendment number 2
Yes: 13 • No: 29
House vote • 2/12/2025
(Electrical Utilities)Passage of Bill
Yes: 94 • No: 11 • Other: 4
Act No. 41
Effective date 05/12/25
Signed By Governor
Ratified R 60
Roll call Ayes-35 Nays-11
Concurred in House amendment and enrolled
Returned to Senate with amendments
Roll call Yeas-88 Nays-13
Senate amendment amended
Debate adjourned until Thur., 5-1-25
Debate adjourned
Debate adjourned until Thur., 4-24-25
Scrivener's error corrected
Roll call Ayes-38 Nays-3
Read third time and returned to House with amendments
Amended
Roll call Ayes-41 Nays-3
Read second time
Amended
Amended
Committee Amendment Adopted
Special order, set for March 27, 2025
Committee report: Favorable with amendment Judiciary
Referred to Subcommittee: Rankin (ch), Campsen, Massey, Adams, Devine, Elliott, Ott
Referred to Committee on Judiciary
Introduced
S 0623, AN ACT TO EXEMPT GEORGETOWN COUNTY FROM CERTAIN BUILDING REQUIREMENTS AND TO ALLOW THE COUNTY TO INSTEAD ENFORCE AE STANDARDS IN GEORGETOWN COUNTY'S FLOOD DAMAGE PREVENTION ORDINANCE.
Georgetown County Building Requirements
S 0779, A JOINT RESOLUTION TO PROVIDE THAT EACH MEMBER OF THE GENERAL ASSEMBLY SHALL RECEIVE A MONTHLY LEGISLATIVE EXPENSE ALLOWANCE OF ONE THOUSAND DOLLARS; TO PROVIDE FOR THE ALLOCATION OF LEGISLATIVE EXPENSE ALLOWANCE PAYMENTS BETWEEN MEMBERS WHOSE SEATS WERE VACATED DURING FISCAL YEAR 2025-2026 AND THE MEMBERS ELECTED TO FILL THE VACANCY; AND TO PROVIDE THAT MEMBERS OF THE GENERAL ASSEMBLY WHOSE SEATS WERE VACATED DUE TO THE MEMBER BEING CONVICTED OF OR PLEADING GUILTY OR NOLO CONTENDERE TO A FELONY ARE NOT ENTITLED TO A LEGISLATIVE EXPENSE ALLOWANCE PAYMENT PURSUANT TO THIS JOINT RESOLUTION.
Legislative Expense Allowance
H 5261, A JOINT RESOLUTION TO EXTEND THE DEADLINE FOR RECEIVING ALCOHOL SERVER TRAINING AS PROVIDED FOR IN CHAPTER 3, TITLE 61 TO MAY 1, 2026.
Alcohol Server Training
S 1162, AN ACT TO AMEND ACT 509 OF 1982, AS AMENDED, RELATING TO THE ELECTION OF TRUSTEES OF ANDERSON COUNTY SCHOOL DISTRICT 2, SO AS TO PROVIDE THAT SIX MEMBERS OF THE SEVEN-MEMBER GOVERNING BODY MUST BE ELECTED FROM SINGLE-MEMBER DISTRICTS.
Anderson County School District No. 2
H 5127, A JOINT RESOLUTION TO APPROPRIATE MONIES FROM THE CAPITAL RESERVE FUND FOR FISCAL YEAR 2025-2026, AND TO ALLOW UNEXPENDED FUNDS APPROPRIATED TO BE CARRIED FORWARD TO SUCCEEDING FISCAL YEARS AND EXPENDED FOR THE SAME PURPOSES.
Capital Reserve Fund appropriation
S 1062, A JOINT RESOLUTION TO APPROVE REGULATIONS OF THE STATE COMMISSION ON HIGHER EDUCATION, RELATING TO DETERMINATION OF RATES OF TUITION AND FEES, DESIGNATED AS REGULATION DOCUMENT NUMBER 5443, PURSUANT TO THE PROVISIONS OF ARTICLE 1, CHAPTER 23, TITLE 1 OF THE SOUTH CAROLINA CODE OF LAWS.
JR to Approve Reg. Doc. No. 5443