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Regulatory Matters | 9 Months Ended
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Sep. 30, 2025
Regulated Operations [Abstract] |
Regulatory Matters | Note 13. Regulatory Matters Regulatory Matters Involving Potential Loss Contingencies As a result of issues generated in the ordinary course of business, the Companies are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For regulatory matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters that the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any estimated range is based on currently available information, involves elements of judgment and significant uncertainties and may not represent the Companies’ maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on the Companies’ financial position, liquidity or results of operations. Other Regulatory Matters Other than the following matters, there have been no significant developments regarding key legislation affecting operations or key regulatory developments disclosed in Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2024. Virginia 2020 Legislation - Recent Development Energy Efficiency The VCEA includes an energy efficiency target of 5% energy savings, as measured from a 2019 baseline, through verifiable energy efficiency programs by the end of 2025 with future targets to be set by the Virginia Commission. Virginia Power has the opportunity to offset the lost revenues with margins on program spend if certain targets are achieved and can also seek recovery of the lost revenues associated with energy efficiency programs if such reductions are found to have caused Virginia Power to earn more than 50 basis points below a fair rate of return on its rates for generation and distribution services. In February 2025, the Virginia Commission issued its order establishing energy savings targets for Virginia Power of 3.00% for 2026, 4.00% for 2027 and 5.00% for 2028, as measured from a 2019 baseline. Virginia Regulation - Recent Developments 2025 Biennial Review In March 2025, Virginia Power filed its base rate case and accompanying schedules in support of the 2025 Biennial Review in accordance with legislation enacted in Virginia in April 2023. Virginia Power’s earnings test analysis, as filed, demonstrated it earned a combined ROE of 7.77% on its generation and distribution services for the test period, compared to the ROE of 9.70% authorized by the Virginia Commission. Accordingly, no regulatory liability for Virginia Power ratepayer credits to customers has been recorded at September 30, 2025. Virginia Power proposed a base rate increase of $822 million effective January 2026 with an incremental base rate increase of $345 million effective January 2027. Virginia Power submitted an update in August 2025 for a proposed base rate increase of $706 million effective January 2026 with an incremental base rate increase of $256 million effective January 2027 to reflect FERC’s approval of a price cap and floor for certain PJM capacity auctions. Alternatively, Virginia Power has proposed to include purchased electric capacity expenses as a component of fuel expenses instead of base rates. If the move is approved, Virginia Power’s proposed base rate increase would be $458 million effective January 2026 with an incremental base rate increase of $173 million effective January 2027. The base rate proposals reflect necessary investments in assets and operating resources, including the impact of significant inflationary pressures on labor, materials and equipment since the 2023 Biennial Review, required to reliably serve a growing customer base. The proposed base rates reflect an ROE of 10.40% utilizing a common equity capitalization to total capitalization ratio of 52.10%. The ROE authorized by the Virginia Commission will be applied to Virginia Power’s riders prospectively and will also be utilized to measure base rate earnings for the 2027 Biennial Review. This matter is pending. Virginia Fuel Expenses In March 2025, Virginia Power filed its annual fuel factor with the Virginia Commission to recover an estimated $2.6 billion in Virginia jurisdictional projected fuel expense for the rate year beginning July 1, 2025 and a projected $205 million under-recovered balance as of June 30, 2025. Virginia Power has proposed to include purchased electric capacity expenses as a component of fuel expenses, consistent with its filing in the 2025 Biennial Review. In addition to the projected energy-related fuel expense, Virginia Power projects $120 million of purchased electric capacity expense to be incurred with PJM from January 1, 2026 to June 30, 2026. Virginia Power’s proposed fuel rate, including purchased electric capacity expense, represents a fuel revenue increase of $860 million when applied to projected kilowatt-hour sales for the rate year beginning July 1, 2025. In May 2025, the Virginia Commission ordered that Virginia Power’s proposed total fuel factor rate, excluding the purchased electric capacity expense component, be placed into effect on an interim basis beginning July 1, 2025. This matter is pending. Virginia Power Equity Application In April 2025, Virginia Power requested approval from the Virginia Commission to issue and sell to Dominion Energy up to $3.5 billion of authorized but unissued shares of its common stock, no par value, through the end of 2025 to maintain adequate credit metrics and efficient access to capital markets while funding necessary capital expenditures. In June 2025, the Virginia Commission approved the request. Renewable Generation Projects In October 2024, Virginia Power filed a petition with the Virginia Commission for CPCNs to construct or acquire and operate two utility-scale projects totaling approximately 208 MW of solar generation as part of its efforts to meet the renewable generation development targets under the VCEA. The projects, as of October 2024, are expected to cost approximately $605 million in the aggregate, excluding financing costs, and be placed into service between 2026 and 2028. In April 2025, the Virginia Commission approved the petition. In October 2025, Virginia Power filed a petition with the Virginia Commission for CPCNs to construct or acquire and operate six utility-scale projects totaling approximately 84 5 MW of solar generation and two energy storage projects totaling approximately 155 MW as part of its efforts to meet the renewable generation development targets under the VCEA. The projects include Bedford and Pumpkinseed, which were constructed and have been operated as non-jurisdictional generation facilities. The remaining projects are expected to, as of October 2025, cost approximately $2.9 billion, excluding financing costs, and be placed into service between 2028 and 2030. This matter is pending. GTSA Filing In March 2025, Virginia Power filed a petition with the Virginia Commission for approval of Phase IIIB, covering 2024 through 2026, of its plan for electric distribution grid transformation projects as authorized by the GTSA. The plan requests approval for mainfeeder hardening work that Virginia Power undertook o n three mainfeeders in 2024, proposes to continue the mainfeeder hardening project on 20 additional feeders in 2025 through 2026, proposes the continued implementation of a new outage management system previously approved by the Virginia Commission and requests approval of one ne w project, a remote sensing, image management and analytical program. For Phase IIIB, the total proposed capital investment is $278 million and the proposed operations and maintenance investment is $5 million. In September 2025, the Virginia Commission approved the petition. Chesterfield Energy Reliability Center In March 2025, Virginia Power filed a petition with the Virginia Commission for a CPCN to construct and operate the Chesterfield Energy Reliability Center. The project, if approved, is expected to cost approximately $1.5 billion in the aggregate, excluding financing costs, have a generating capacity of 944 MW and be placed into service in 2029. This matter is pending. Riders Other than the following matters, there have been no significant developments regarding the significant riders associated with various Virginia Power projects disclosed in Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2024.
Rider Name |  | Application Date |  | Approval Date |  | Rate Year Beginning |  | Total Revenue Requirement (millions)(1) |  |  | Increase (Decrease) from Previous (millions) |
Rider CCR(2) |  | April 2025 |  | Pending |  | January 2026 |  | $ | 166 |  |  | $ | 63 |
Rider CE(3) |  | October 2024 |  | April 2025 |  | May 2025 |  |  | 182 |  |  |  | 49 |
Rider CE(4) |  | October 2025 |  | Pending |  | May 2026 |  |  | 325 |  |  |  | 143 |
Rider DIST(5) |  | August 2024 |  | May 2025 |  | June 2025 |  |  | 267 |  |  | N/A |
Rider DIST(6) |  | August 2025 |  | Pending |  | June 2026 |  |  | 333 |  |  |  | 66 |
Rider E |  | January 2025 |  | September 2025 |  | November 2025 |  |  | 37 |  |  |  | (35 | )
Rider GEN(7) |  | June 2024 |  | February 2025 |  | April 2025 |  |  | 438 |  |  | N/A |
Rider GEN |  | June 2024 |  | February 2025 |  | April 2026 |  |  | 311 |  |  |  | (127 | )
Rider OSW(8) |  | November 2024 |  | August 2025 |  | September 2025 |  |  | 639 |  |  |  | 153 |
Rider OSW |  | October 2025 |  | Pending |  | September 2026 |  |  | 665 |  |  |  | 26 |
Rider RPS |  | December 2024 |  | August 2025 |  | September 2025 |  |  | 609 |  |  |  | 251 |
Rider SNA(9) |  | October 2024 |  | July 2025 |  | September 2025 |  |  | 207 |  |  |  | 138 |
Rider SNA |  | October 2025 |  | Pending |  | September 2026 |  |  | 233 |  |  |  | 26 |
Rider T1(10) |  | May 2025 |  | August 2025 |  | September 2025 |  |  | 1,343 |  |  |  | 173 |
DSM Riders(11) |  | December 2024 |  | August 2025 |  | September 2025 |  |  | 96 |  |  |  | 10 |
(1) In addition, Virginia Power has a rider associated with another project with a total annual revenue requirement of $17 million and a pending application associated with the Chesterfield Energy Reliability Center described above, which if approved would result in an annual revenue requirement increase of $36 million. (2) In connection with this application, Virginia Power also requests to extend existing rates for Rider CCR by one month through December 2025. (3) Associated with two solar generation projects, two small-scale solar projects and 19 purchased power agreements in addition to previously approved Rider CE projects. (4) Associated with six solar generation projects, including Bedford and Pumpkinseed (non-jurisdictional generation facilities with an aggregate recorded cost of $251 million at September 30, 2025), two energy storage projects, three small-scale solar projects, 10 purchased power agreements and certain costs associated with expanding solar and storage facilities in addition to previously approved Rider CE projects. (5) Rider DIST includes $100 million in total revenue requirement for certain previously approved electric distribution grid transformation projects and $167 million for previously approved phases and proposed phase eight of certain new underground distribution facilities. Rider DIST also results in the consolidation of, and ceases the separate collection of rates under, Riders GT and U effective June 1, 2025. (6) This application includes $120 million in total revenue requirement for certain previously approved electric distribution grid transformation projects, $178 million for previously approved phases and proposed phase nine of certain new underground distribution facilities and $35 million for certain previously approved rural broadband capacity projects, including $25 million being collected under a rider associated with rural broadband capacity projects. If approved, the rider associated with rural broadband capacity projects would be consolidated into Rider DIST and separate collection of rates under the rural broadband rider would cease effective June 1, 2026. (7) Rider GEN includes $348 million in total revenue requirement related to the consolidation of Riders BW, GV and four other riders associated with generation facilities, ceasing the separate collection of rates under these riders effective April 1, 2025 and the extension of existing rates for Rider BW through March 2025. In addition, Virginia Power also received approval to recover costs associated with the Virginia LNG Storage Facility through Rider GEN described in Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2024. (8) The Virginia Commission also approved the establishment of a decommissioning trust fund associated with the CVOW Commercial Project. As a result, the applicable amount included within the revenue requirement for Rider OSW will be allocated for such purposes. (9) The Virginia Commission also approved Virginia Power’s request for cost recovery of approximately $1.7 billion through Rider SNA for the second phase of the nuclear life extension program which includes investments for calendar years 2025 through 2027. (10) Consists of $561 million for the transmission component of Virginia Power’s base rates and $782 million for Rider T1. (11) Associated with three redesigned energy efficiency programs and one new and two redesigned demand response programs with a $218 million cost cap, with the ability to exceed the cost cap by no more than 15%. Electric Transmission Projects Other than the following matters, there have been no significant developments regarding the significant Virginia Power electric transmission projects disclosed in Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2024.
Description and Location of Project |  | Application Date |  | Approval Date |  | Type of Line |  | Miles of Lines |  | Cost Estimate (millions)(1) |
Construct new Aspen and Golden substations, transmission lines and related projects in Loudoun County, Virginia |  | March 2024 |  | February 2025(2) |  | 500- 230 kV |  | 10 |  | $ | 705 |
Construct new Apollo-Twin Creek transmission lines, new substations and related projects in Loudoun County, Virginia |  | March 2024 |  | February 2025(2) |  | 230 kV |  | 2 |  |  | 285 |
Rebuild and construct new Fentress-Yadkin transmission lines and related projects in the City of Chesapeake, Virginia |  | June 2024 |  | February 2025 |  | 500 kV |  | 14 |  |  | 205 |
Partial rebuild, reconductor and construct new Network Takeoff transmission lines and related projects in the Counties of Fairfax and Loudoun, Virginia |  | July 2024 |  | March 2025 |  | 230 kV |  | 6 |  |  | 170 |
Rebuild Aquia Harbour-Possum Point transmission lines and related projects in the Counties of Stafford and Prince William and the City of Fredericksburg, Virginia |  | August 2024 |  | March 2025 |  | 500- 230 kV |  | 32 |  |  | 210 |
Partial rebuild, reconductor and construct new New Post transmission lines and related projects in the Counties of Caroline and Spotsylvania, Virginia |  | August 2024 |  | May 2025 |  | 230 kV |  | 38 |  |  | 120 |
Construct new Centreport transmission line, substation and related projects in Stafford County, Virginia |  | September 2024 |  | June 2025 |  | 230 kV |  | 3 |  |  | 55 |
Partial rebuild and construct new Meadowville transmission lines, substations and related projects in Chesterfield County, Virginia |  | October 2024 |  | June 2025 |  | 230 kV |  | 11 |  |  | 190 |
Construct new Carmel Church and Ruther Glen transmission lines, substations and related projects in Caroline County, Virginia |  | December 2024 |  | September 2025 |  | 230 kV |  | 7 |  |  | 85 |
Construct new Nebula transmission lines, substation and related projects in Mecklenburg County, Virginia |  | January 2025 |  | October 2025 |  | 230 kV |  | 15 |  |  | 130 |
Construct new Technology Boulevard transmission lines, substation and related projects in Henrico County, Virginia |  | March 2025 |  | Pending |  | 230 kV |  | 5 |  |  | 60 |
Construct new Hornbaker transmission lines, switching station and related projects in Prince William County, Virginia |  | March 2025 |  | Pending |  | 230 kV |  | 5 |  |  | 95 |
Construct new Golden-Mars transmission lines and related projects in Loudoun County, Virginia |  | March 2025 |  | Pending |  | 500- 230 kV |  | 11 |  |  | 525 |
Construct new Duval-Midlothian transmission lines, substation and related projects in Chesterfield County, Virginia |  | April 2025 |  | Pending |  | 230 kV |  | 7 |  |  | 125 |
Rebuild Chickahominy-Elmont transmission line, new future transmission line and related projects in the Counties of Charles City, Henrico and Hanover, Virginia |  | May 2025 |  | Pending |  | 500- 230 kV |  | 28 |  |  | 190 |
Rebuild Septa-Yadkin transmission line, partial rebuild of Suffolk-Thrasher transmission line and related projects in Isle of Wight County and the Cities of Chesapeake and Suffolk, Virginia |  | June 2025 |  | Pending |  | 500- 230 kV |  | 33 |  |  | 250 |
Partial rebuild Chesterfield-Lanexa transmission lines in the Counties of Henrico, Charles City and New Kent, Virginia |  | September 2025 |  | Pending |  | 230- 115 kV |  | 58 |  |  | 150 |
Rebuild Charlottesville-Dooms transmission lines in the Counties of Albemarle and Augusta and the City of Charlottesville, Virginia |  | October 2025 |  | Pending |  | 230 kV |  | 22 |  |  | 125 |
(1) Represents the cost estimate included in the application except as updated in the approval if applicable. In addition, Virginia Power had various other transmission projects approved during 2025 with aggregate cost estimates of approximately $65 million. (2) The final order of the Virginia Commission has been appealed to the Supreme Court of Virginia. This matter is pending. Virginia Regulation - Key Development affecting 2024 2023 Biennial Review In February 2024, the Virginia Commission issued its order in the 2023 Biennial Review. In connection with the order, Virginia Power recorded a net benefit of $17 million ($12 million after-tax) in the first quarter of 2024 within impairment of assets and other charges in its Consolidated Statements of Income for a regulatory asset for previously unrecovered severe weather event costs, which were amortized by the end of 2024. North Carolina Regulation Virginia Power Fuel Filing In August 2025, Virginia Power submitted its annual filing to the North Carolina Commission to adjust the fuel component of its electric rates. In October 2025, Virginia Power subsequently updated its annual filing following a change in law which provides for recovery of purchased electric capacity expenses as a component of fuel. Virginia Power proposed a total $49 million increase to the fuel component of its electric rates for the rate year beginning February 1, 2026. This matter is pending. South Carolina Regulation - Recent Developments Cost of Fuel DESC’s retail electric rates include a cost of fuel component approved by the South Carolina Commission which may be adjusted periodically to reflect changes in the price of fuel purchased by DESC. In February 2025, DESC filed with the South Carolina Commission a proposal to increase the total fuel cost component of retail electric rates. DESC’s proposed adjustment is designed to recover DESC’s current base fuel costs, including its existing under-collected balance, over the 12-month period beginning with the first billing cycle of May 2025. In addition, DESC proposed an increase to its variable environmental and avoided capacity cost component. The net effect is a proposed annual increase of $154 million. In March 2025, DESC and the South Carolina Office of Regulatory Staff filed a settlement agreement with the South Carolina Commission for approval to make certain adjustments to the February 2025 filing that would result in an inconsequential change to the proposed annual increase. In April 2025, the South Carolina Commission approved the settlement agreement, with rates effective with the first billing cycle of May 2025. Electric DSM Programs DESC has approval for a DSM rider through which it recovers expenditures related to its DSM programs. In January 2025, DESC filed an application with the South Carolina Commission seeking approval to recover $46 million of costs and net lost revenues associated with these programs, along with an incentive to invest in such programs. DESC requested that rates be effective with the first billing cycle of May 2025. In April 2025, the South Carolina Commission approved the request, effective with the first billing cycle of May 2025. Electric - Transmission Project In December 2024, DESC filed an application with the South Carolina Commission requesting approval of a CPCN to construct and operate the Ritter-Yemassee Transmission Line #2, comprised of a 17-mile 230 kV transmission line and associated facilities in Colleton and Hampton Counties, South Carolina with an estimated total project cost of $55 million. In April 2025, the South Carolina Commission approved the application. Natural Gas Rates In June 2025, DESC filed with the South Carolina Commission its monitoring report for the 12-month period ended March 31, 2025 with a total revenue requirement of $596 million. This revenue requirement represents a $17 million base rate increase under the terms of the Natural Gas Rate Stabilization Act effective with the first billing cycle of November 2025. In September 2025, the South Carolina Commission approved a total revenue requirement of $594 million, representing a $15 million base rate increase after certain adjustments, effective with the first billing cycle of November 2025. South Carolina Regulation - Key Development affecting 2024 Electric Base Rate Case In the third quarter of 2024, Dominion Energy recorded a charge of $58 million ($44 million after tax) (reflected within the Corporate and Other segment), including $50 million to write down certain materials and supplies inventory presented within impairment of assets and other charges, in connection with the electric base rate case in South Carolina as discussed in Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2024.

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