AddedRisk Factors
addition, the cost of the CVOW Commercial Project could be adversely affected by the impact of applicable tariffs, including any potential impact of Section 232 investigations.
DDominion Energy
Dominion Energy, headquartered in Richmond, Virginia and incorporated in Virginia in 1983, provides service to approximately 4.1 million primarily electric utility customers in Virginia, North Carolina and South Carolina. 10-K, Item 1
- Employees
- 15,200
- Headquarters
- Richmond, VA
- Next results
- around Feb 22, 2027
10-K 0001193125-26-063120 (2026-02-23) vs 10-K 0000950170-25-028387 (2025-02-27)
| Section | Compared text | Words now | Changed |
|---|---|---|---|
| Risk Factors | Item 1A | 10,059 | 15.4% |
| MD&A | Item 7 | 15,756 | 23.3% |
| Legal Proceedings | Item 3, via Note 13 – Regulatory Matters | 6,310 | 36.9% |
| Accounting Policies | Item 8, Note 2 – Significant Accounting Policies | 10,224 | 18.9% |
The redline: what was cut and what was added
In each section, the paragraph that changed most, marked against last year's 10-K:
cut words struck through, new words highlighted and underlined.
Legal Proceedings 471 words changed in this paragraph; it is 48% similar to last year's version.
Description and Location of Project Application Approval Type of Miles of Cost Estimate of Project Date Date Line Lines (millions)(1) Construct new Germanna substation, transmission November 2023 August 2024 230 kV 2 $55 line and related projects in Culpeper County, Virginia Construct Daves Store transmission line extension February 2024 October 2024 230 kV 3 70 in Prince William County, Virginia Construct new Aspen and Golden substations, March 2024 February 2025 500- 10 705 transmission lines and related March 2024 February 2025(2) 500- 10 705 projects in Loudoun County, Virginia 230 kV County, Virginia Partial rebuild Fredericksburg-Aquia Harbour Construct new Apollo-Twin Creeks transmission lines, new substations and March 2024 February 2025 230- 24 135 transmission lines and related projects in Stafford 115 kV County and the City of Fredericksburg, Virginia Construct new Apollo-Twin Creek transmission lines, March 2024 February 2025 2025(2) 230 kV 2 285 new substations and related projects in Loudoun County, Virginia Rebuild Dooms-Harrisonburg transmission lines April 2024 February 2025 230 kV 22 60 and related projects in the Counties of Augusta and Rockingham and the Town of Grottoes, Virginia Rebuild and construct new Fentress-Yadkin transmission lines and related June 2024 Pending February 2025 500 kV 14 205 transmission lines and related projects in the City of Chesapeake, Virginia Partial rebuild, reconductor and construct new Network Takeoff transmission July 2024 Pending March 2025 230 kV 6 170 Network Takeoff transmission lines and related projects in the Counties of Fairfax and Loudoun, Virginia Rebuild Aquia Harbor-Possum Point transmission August 2024 Pending 500- 32 210 lines and related projects August 2024 March 2025 500- 32 210 in the Counties of 230 kV Stafford and Prince William and the City of Fredericksburg, 230 kV Virginia Partial rebuild, reconductor and construct new New Post transmission lines August 2024 Pending May 2025 230 kV 38 120 New Post transmission lines and related projects in the Counties of Caroline and Spotsylvania, Virginia Construct new Centreport transmission line, September 2024 Pending 230 kV 3 55 substation and related projects in September 2024 June 2025 230 kV 3 55 Stafford County, Virginia Partial rebuild and construct new Meadowville transmission lines, substations October 2024 Pending June 2025 230 kV 11 190 transmission lines, substations and related projects in Chesterfield County, Virginia Construct new Carmel Church and Ruther Glen transmission lines, substations December 2024 Pending September 2025 230 kV 7 85 transmission lines, substations and related projects in Caroline County, Virginia Construct new Nebula transmission lines, January 2025 Pending 230 kV 15 130 substation and related projects in January 2025 October 2025 230 kV 15 130 Mecklenburg County, Virginia Construct new Culpeper Technology transmission lines, substations and February 2025 Pending 230 kV 13 255 lines, substations and related projects in the Counties of Culpeper, Orange and Fauquier and the Town of Culpeper, Virginia Construct new Technology Boulevard transmission lines, substation and March 2025 February 2026 230 kV 5 60 related projects in Henrico County, Virginia Construct new Hornbaker transmission lines, switching station and March 2025 December 2025 230 kV 5 95 related projects in Prince William County, Virginia Construct new Golden-Mars transmission lines and related projects in March 2025 Pending 500- 11 525 Loudoun County, Virginia 230 kV Construct Duval-Midlothian transmission lines, substation and related April 2025 February 2026 230 kV 7 125 projects in Chesterfield County, Virginia Rebuild Chickahominy-Elmont transmission line, new future transmission May 2025 January 2026 500- 28 190 line and related projects in the Counties of Charles City, Henrico and 230 kV Hanover, Virginia Rebuild Septa-Yadkin transmission line, partial rebuild of Suffolk-Thrasher June 2025 December 2025 500- 33 250 transmission line and related projects in Isle of Wight County and the Cities 230 kV of Chesapeake and Suffolk, Virginia Partial rebuild Chesterfield-Lanexa transmission lines in the Counties of September 2025 Pending 230- 58 150 Henrico, Charles City and New Kent, Virginia 115 kV Rebuild Charlottesville-Dooms transmission lines in the Counties of October 2025 Pending 230 kV 22 125 Albemarle and Augusta and the City of Charlottesville, Virginia Construct West Creek transmission line, substation and related projects January 2026 Pending 230 kV 7 100 in the County of Goochland, Virginia
Source: Item 3, via Note 13 – Regulatory Matters, 10-K 0001193125-26-063120 vs Item 3, via Note 13 – REGULATORY MATTERS, 10-K 0000950170-25-028387
Risk Factors 230 words changed in this paragraph; it is 42% similar to last year's version.
The Companies may be materially adversely affected by negative publicity or the inability of Dominion Energy to meet its stated commitments. From time to time, political and public sentiment may result in a significant amount of adverse press coverage and other adverse public statements affecting the Companies. Public sentiment may be affected by certain events outside of the Companies’ control, such as outages caused by severe weather events or increases in approved rates to recover higher than anticipated market rates for fuel used in electric generation. Any failure by Dominion Energy to realize its commitments to achieve net zero carbon and methane emissions by 2050, enhance the customer experience or other long-term goals could lead to adverse press coverage and other adverse public statements affecting the Companies. The ability to comply with some or all of Dominion Energy’s voluntary commitments may be outside of its control. For example, the ability to reduce emissions while meeting the Companies’ increasing demand growth is expected to be dependent on the technological and economic feasibility of large-scale battery storage, carbon capture and storage, small modular reactors, hydrogen and/or other clean energy technologies. Dominion Energy is also dependent on the actions of third parties to meet the expanded commitment regarding Scope 2 emissions and Scope 3 emissions. If downstream customers or upstream suppliers do not sufficiently reduce their GHG emissions, Dominion Energy may not achieve its net zero emissions goal. In addition, while the Atlantic Coast Pipeline Project was cancelled in July 2020 and the legal proceedings and governmental investigations relating to the abandonment of the NND Project have been resolved, there is a risk that lingering negative publicity may continue. Adverse press coverage and other adverse statements, whether or not driven by political or public sentiment, may also result in investigations by regulators, legislators and law enforcement officials or in legal claims as well as adverse outcomes.
Source: Item 1A, 10-K 0001193125-26-063120 vs Item 1A, 10-K 0000950170-25-028387
MD&A 155 words changed in this paragraph; it is 40% similar to last year's version.
Net cash from Dominion Energy’s financing activities decreased $2.4 increased $9.4 billion, primarily due to a $9.5 billion decrease due to the absence of net repayments on 364-day term loan facilities in 2024 versus ($4.8 billion), an increase in net issuances of long-term debt ($3.9 billion), a decrease in 2023, net repayments of short-term debt ($2.0 ($1.4 billion), an increase in capital contributions from Stonepeak to OSWP, net of distributions from OSWP to Stonepeak ($951 million), the absence of the repurchase and redemption of the Series B Preferred Stock ($801 million) and net repayment of supplemental credit facility borrowings ($450 million), partially offset by a $6.8 billion increase due to net issuances of long-term debt in 2024 versus net repayments in 2023, an increase from the sale of a noncontrolling interest in, as well as capital contributions from Stonepeak to, OSWP ($2.9 billion) and ($801 million), an increase in the issuance of common stock ($638 million). ($756 million) and the absence of supplemental credit facility repayments in 2024 ($450 million), partially offset by the impacts from the sale of a noncontrolling interest in OSWP to Stonepeak ($2.6 billion) and a decrease due to the issuance of securitization bonds in 2024 and higher repayments of such bonds in 2025 ($1.4 billion).
Source: Item 7, 10-K 0001193125-26-063120 vs Item 7, 10-K 0000950170-25-028387
Accounting Policies 80 words changed in this paragraph; it is 33% similar to last year's version.
Dominion Energy 2024 2023 Year Ended December 31, 2024 2023 2022 As Previously Reported Adjustments As Revised As Previously Reported Adjustments As Revised (millions) Cash paid during the year for: Interest Net income including noncontrolling interests $ 2,071 $ (90) $ 1,981 $ 2,031 $ (69) $ 1,962 Operating Activities Deferred income taxes (302) 67 (235) 1,474 53 1,527 Other operating assets and related charges, excluding capitalized amounts $ 1,900 $ 1,991 $ 1,408 Income taxes 840 286 139 Significant noncash investing and financing activities:(1)(2) Accrued capital expenditures 1,268 1,085 979 Leases(3) 233 255 144 liabilities (235) 23 (212) (564) 16 (548) Net cash provided by operating activities 5,018 — 5,018 6,572 — 6,572
Source: Item 8, Note 2 – Significant Accounting Policies, 10-K 0001193125-26-063120 vs Item 8, Note 2 – SIGNIFICANT ACCOUNTING POLICIES, 10-K 0000950170-25-028387
Every change, by type
Sentences and paragraphs of D's Risk Factors and MD&A, 10-K 2026-02-23 against 10-K 2025-02-27. Each links to the text at sec.gov.
Quiet changes are sentences kept from last year with one to four words changed, at least one of them a hedge, a modal or a qualifier
(may, could, will, not, significant, material…). A year or date rolling forward is not counted.
The full word list
adverse, adversely, all, although, anticipate, anticipates, any, approximately, believe, believes, can, cannot, certain, could, expect, expects, generally, however, if, intend, intends, largely, likely, many, material, materially, may, might, most, must, never, no, not, possible, primarily, probable, should, significant, significantly, some, substantial, substantially, unlikely, will, would
AddedRisk Factors
approvals. Even if facility construction, expansion, electric transmission line, conversion and other infrastructure projects are completed, the total costs of the projects may be higher than anticipated and the performance of the business of the Companies following completion of the projects may not meet expectations. If these infrastructure projects are not completed, are delayed or are subject to unanticipated costs, certain costs may not be approved for recovery or otherwise be recoverable through regulatory mechanisms that may be available. Further, the Companies could become obligated to make delay or termination payments or become obligated for other damages under contracts, could experience the loss or reduction of tax credits or incentives, the inability to transfer related tax credits, or delayed or diminished returns, and could be required to write off all or a portion of their investments in such projects.
AddedRisk Factors
19 different locations, including 12 at Virginia Power. The Companies also may face litigation concerning their coal ash facilities.
RemovedRisk Factors
RemovedRisk Factors
RemovedRisk Factors
RewordedRisk Factors
RewordedRisk Factors
RewordedRisk Factors
The Companies expect that existing environmental laws and regulations may be revised and/or new laws may be adopted adopted, including regulation of GHG emissions emissions, which could have an adverse impact on the Companies’ business (risks relating to regulation of GHG emissions from existing fossil fuel-fired electric generating units are discussed in more detail above and below). business.
RewordedRisk Factors
The construction of such projects is expected to take several years, is typically confined within a limited geographic area or difficult environments and could be subject to delays, supply chain disruption, availability of critical components, cost overruns, inflation, labor disputes or shortages and other factors that could cause the total cost of the project to exceed the anticipated amount and adversely affect the Companies’ financial performance and/or impair the Companies’ ability to execute the business plan for the project as scheduled. amount.
RewordedRisk Factors
If the Companies are unable to complete the construction of the CVOW Commercial Project or decide in the future to delay or cancel the project, the Companies may not be able to recover all or a portion of their investment in the project and may incur substantial cancellation payments under existing contracts or other substantial costs associated with any such delay or cancellation.
RewordedRisk Factors
Recent legislative and regulatory changes that are impacting or could impact the Companies include legislation enacted in Virginia in April 2023, the IRA, the VCEA, the 2017 Tax Reform Act Act, the OBBBA and tariffs imposed on various components required for construction of the CVOW Commercial Project or imported solar panels by the U.S. government in 2018. 2025 and 2018, respectively.
RewordedRisk Factors
To achieve Dominion Energy’s commitment to net zero emissions by 2050 and comply with the requirements of the VCEA, VCEA and projected demand while maintaining reliability, the Companies are currently simultaneously developing or constructing several electric generation projects, including subsequent license renewal projects at Surry nuclear facilities in Virginia and North Anna, South Carolina, the CVOW Commercial Project, the Chesterfield Energy Reliability Center, several electric transmission projects and various solar projects.
RewordedRisk Factors
In addition, the timely installation of the turbines is dependent on the completion and continued availability of a Jones Act compliant vessel currently under construction. a 20-month lease agreement which commenced in September 2025 between Virginia Power and an affiliated entity.
RewordedRisk Factors
Projects may not be able to be completed on time or in accordance with estimated costs as a result of weather conditions, need for new land and right of ways, delays in obtaining or failure to obtain or maintain regulatory and other, including PJM, approvals, changes in laws or regulations, regulations or other regulatory or administrative action or inaction, the outcome of legal proceedings and judicial actions, delays in obtaining key materials, labor difficulties, difficulties with partners or potential partners, concerns raised during stakeholder engagement, a decline in the credit strength of counterparties or vendors, inflation, the impact of applicable tariffs or other factors beyond the Companies’ control.
RewordedRisk Factors
RewordedRisk Factors
For other factors that may cause actual results to differ materially from those indicated in additional information concerning any forward-looking statement or projection contained in this report, see Forward-Looking Statements in Item 7.
RewordedRisk Factors
Deterioration in the Companies’ creditworthiness, as evaluated by credit rating agencies or otherwise, or declines in market reputation either for the Companies or their industry in general, or general financial market disruptions outside of the Companies’ control could increase their cost of borrowing or restrict their ability to access one or more financial markets.
Quiet changesRisk Factors
Accordingly, actual costs incurred may differ materially from insured or reserved amounts and may not be recoverable, in whole or in part, by insurance or in rates from customers.
Quiet changesRisk Factors
Cost recovery for these initiatives will require approval by the Virginia Commission which may be denied or materially altered to the detriment of the Companies.
Quiet changesRisk Factors
Further, while the Companies believe that they operate their ash ponds and landfills in compliance with applicable state safety regulations, a release of coal ash with a significant environmental impact could result in significant remediation costs, civil and/or criminal penalties, claims, litigation, increased regulation and compliance costs, and reputational damage, and could impact the financial condition of the Companies.
AddedMD&A
Commercial Project as a result of a revised total project cost estimate of approximately $11.5 billion (excluding financing costs) which reflects a temporary suspension of work order and an estimated impact of certain tariffs which became effective during 2025 as well as the previously included revised estimate of network upgrade costs assigned by PJM to the CVOW Commercial Project and cost sharing mechanism included in the Virginia Commission’s December 2022 order. The expected total project cost reflects an increase of $0.2 billion, relative to Virginia Power’s October 2025 Rider OSW filing, associated with projected installation timeline changes arising from the temporary suspension of work from the BOEM Director’s Order issued in December 2025 until a preliminary injunction was granted by the U.S District Court for the Eastern District of Virginia in January 2026, which allowed work to resume. The estimated total project costs also include $0.6 billion of tariffs on equipment expected to be delivered from March 2025 through March 2026 that originates from Mexico, Canada, a European Union member or other applicable countries and on equipment expected to be delivered from March 2025 through early 2027 that contains steel. Such amount is inclusive of approximately $0.2 billion associated with tariffs on equipment expected to be delivered from March 2025 through March 2026 that originates from Mexico, Canada, a European Union member or other applicable countries that were the subject of a U.S. Supreme Court’s ruling on February 20, 2026. Dominion Energy is currently unable to estimate the expected impact of the ruling issued by the U.S. Supreme Court on February 20, 2026, on its financial position, results of operations and/or cash flows.
AddedMD&A
•$21 million in sales of environmental credits generated from renewable natural gas production in 2025; and
AddedMD&A
•A $29 million decrease associated with severe weather events affecting Virginia Power.
AddedMD&A
Year Ended December 31, 2025 % Change 2024 % Change 2023 Electricity supplied 18.4 2% 18.0 22% 14.8 (million MWh) Renewable natural gas 1.1 N/A — N/A — supplied (million MMBtu)
AddedMD&A
Year Ended December 31, 2025 2024 2023 (millions, except EPS) Specific items attributable to operating segments $ (28) $ (222) $ 336 Specific items attributable to 60 (136) (89) Corporate and Other segment Net income (expense) from specific items 32 (358) 247 Corporate and other operations: Interest expense, net (519) (537) (564) Equity method investments (5) (5) 6 Pension and other postretirement benefit plans 232 277 232 Corporate service company costs (52) (79) (126) Other 12 (32) 7 Net expense from corporate and other operations (332) (376) (445) Total net expense $ (300) $ (734) $ (198) EPS impact $ (0.41) $ (0.97) $ (0.33)
AddedMD&A
Dominion Energy’s short-term financing is primarily supported by its joint revolving credit facility. In April 2025, Dominion Energy amended its joint revolving credit facility to, among other things, increase the facility limit from $6.0 billion to $7.0 billion and extend the maturity date from June 2026 to April 2030. In addition, in April 2025, Dominion Energy entered into a $1.0 billion 364-day revolving credit agreement.
AddedMD&A
Dominion Energy’s credit ratings and outlooks at February 16, 2026 are as follows:
AddedMD&A
The IRA, among other things, provides for investment and production tax credits for clean energy technologies until at least 2032, provides for transferability of certain tax credits and imposes a 15% alternative minimum tax on corporations with GAAP net income greater than $1 billion, as adjusted for certain items. Entities that are subject to the alternative minimum tax may use tax credits to reduce the liability by up to 75% and will receive a tax credit carryforward with an indefinite life that can be claimed against regular tax in future years. In 2025, the OBBBA modified many of the tax credits for renewable and clean energy technologies created under the IRA. Provisions include the termination of the production and investment tax credits for wind and solar for facilities placed in service after 2027 (except for certain facilities that commence construction by July 2026 and meet certain safe harbor requirements) and a phase out of other production and investment tax credits for certain clean energy facilities, including battery storage and small modular reactors, for projects beginning construction through 2035, after which the credits are fully phased out. The OBBBA restricts the availability of tax credits for certain prohibited foreign entities and projects receiving material assistance from certain foreign entities as well as the extension of the production tax credit for renewable natural gas sold through 2029. Dominion Energy has considered the IRA and the OBBBA in recording its provision for income taxes and continues to evaluate the provisions of these tax laws, the ultimate impact of which is subject to pending guidance and interpretations, the effects of which could be material to Dominion Energy’s results of operations, financial condition and/or cash flows; existing regulatory frameworks provide rate recovery mechanisms that could substantially mitigate such impacts for its regulated electric utilities.
RemovedMD&A
RemovedMD&A
RemovedMD&A
RemovedMD&A
RemovedMD&A
RemovedMD&A
RemovedMD&A
RemovedMD&A
RemovedMD&A
RemovedMD&A
RemovedMD&A
RemovedMD&A
RewordedMD&A
Net cash from Dominion Energy’s financing activities decreased $2.4 increased $9.4 billion, primarily due to a $9.5 billion decrease due to the absence of net repayments on 364-day term loan facilities in 2024 versus ($4.8 billion), an increase in net issuances of long-term debt ($3.9 billion), a decrease in 2023, net repayments of short-term debt ($2.0 ($1.4 billion), an increase in capital contributions from Stonepeak to OSWP, net of distributions from OSWP to Stonepeak ($951 million), the absence of the repurchase and redemption of the Series B Preferred Stock ($801 million) and net repayment of supplemental credit facility borrowings ($450 million), partially offset by a $6.8 billion increase due to net issuances of long-term debt in 2024 versus net repayments in 2023, an increase from the sale of a noncontrolling interest in, as well as capital contributions from Stonepeak to, OSWP ($2.9 billion) and ($801 million), an increase in the issuance of common stock ($638 million). ($756 million) and the absence of supplemental credit facility repayments in 2024 ($450 million), partially offset by the impacts from the sale of a noncontrolling interest in OSWP to Stonepeak ($2.6 billion) and a decrease due to the issuance of securitization bonds in 2024 and higher repayments of such bonds in 2025 ($1.4 billion).
RewordedMD&A
Net income from discontinued operations including noncontrolling interests increased $322 million, primarily due to the absence of charges reflecting the recognition of deferred taxes on the outside basis of stock associated with East Ohio, PSNC, Questar Gas and Wexpro meeting the classification as held for sale ($835 million), a decrease in impairments associated with the East Ohio and Questar Gas Transactions ($197 million), the absence of depreciation expense associated with the East Ohio, PSNC and Questar Gas Transactions upon meeting the classification as held for sale ($211 million), the absence of interest expense on variable rate debt secured by Dominion Energy’s interest in Cove Point ($72 million), a gain upon the closing of the Questar Gas Transaction ($42 million), the absence of an impairment charge associated with the impairment of Birdseye ($34 million), the absence of charges associated with the impairment of the Madison solar project ($19 million) and the absence of an impairment charge of certain nonregulated solar assets ($11 million), partially offset by the absence of a gain on the sale of Dominion Energy’s remaining noncontrolling interest in Cove Point ($348 million), the absence of earnings from operations following the closing of the East Ohio Transaction ($299 million) and Questar Gas Transaction ($138 million), the absence of equity method earnings from the sale of Dominion Energy’s noncontrolling interest in Cove Point ($163 million), a loss on the closing of the East Ohio Transaction ($109 million), charges for employee benefit items related to the East Ohio Transaction ($33 million), a loss on the closing of the PSNC Transaction ($31 million) and higher tax expense associated with the PSNC Transaction ($16 million).
RewordedMD&A
Net cash used in Dominion Energy’s investing activities decreased $4.0 increased $9.8 billion, primarily due to the absence of net proceeds from the East Ohio, Questar Gas and PSNC Transactions ($9.2 billion) and an increase in distributions from equity method affiliates ($125 million), partially offset by the absence of the net proceeds from the sale of the remaining noncontrolling interest in Cove Point ($3.3 billion), an increase in plant construction and other property additions ($2.0 billion) ($443 million) and higher the absence of distributions from equity method affiliates in 2024 ($126 million), partially offset by lower acquisitions of solar development projects ($205 ($217 million).
RewordedMD&A
RewordedMD&A
Such estimate could potentially change for items, certain of which are beyond the Companies’ Dominion Energy’s control, including but not limited to actual network upgrade costs allocated by PJM, fuel for transportation and installation, the impact of applicable tariffs, if any, costs to maintain necessary permits, approvals tariffs including any potential impact of Section 232 investigations and authorizations, ability of key suppliers and contractors to timely satisfy their obligations under existing contracts, marine wildlife and/or any severe weather events. litigation ruled on by the U.S.
RewordedMD&A
Noncontrolling interests decreased $53 increased $120 million, due to the 50% noncontrolling interest in the CVOW Commercial Project sold to Stonepeak in October 2024, consisting of Stonepeak’s share of the earnings associated with the CVOW Commercial Project subsequent to closing, which includes a charge $154 million share of charges for costs not expected to be recovered from customers on the CVOW Commercial Project ($103 million) partially offset by its share of the remaining earnings associated with the CVOW Commercial Project subsequent to closing. Project.
RewordedMD&A
Noncontrolling interests decreased $53 increased $120 million, due to the 50% noncontrolling interest in the CVOW Commercial Project sold to Stonepeak in October 2024, consisting of Stonepeak’s share of the earnings associated with the CVOW Commercial Project subsequent to closing, which includes a charge $154 million share of charges for costs not expected to be recovered from customers on the CVOW Commercial Project ($103 million) partially offset by its share of the remaining earnings associated with the CVOW Commercial Project subsequent to closing. Project.
RewordedMD&A
The discount rates used to calculate pension cost and other postretirement benefit cost ranged from 5.84% to 5.87% for pension plans and 5.83% to 5.86% for other postretirement benefit plans in 2025, ranged from 5.37% to 5.75% for pension plans and 5.40% to 5.74% for other postretirement benefit plans in 2024, 2024 and ranged from 5.65% to 5.75% for pension plans and 5.69% to 5.70% for other postretirement benefit plans in 2023 and ranged from 3.06% to 3.19% for pension plans and 3.04% to 5.03% for other postretirement benefit plans in 2022. 2023.
RewordedMD&A
RewordedMD&A
Until specific state implementation plans are developed for the EPA ultimately takes final action on the proposed rulemakings and publishes all final rules and/or Dominion Energy has sufficient time to develop implementation strategies for these final rules, in the federal register, Dominion Energy is unable to predict whether or to what extent the new rules will ultimately require additional controls or other actions.
RewordedMD&A
Month Type Entity Principal (1) Rate Stated Maturity (millions) Debt scheduled to mature in 2024 $ 1,429 2025 Multiple $1,663 various Early repurchases & and redemptions February Senior secured notes Eagle Solar 279 4.820% 2042 October Tax-exempt bonds DETC 27 3.800% 2033 October Junior subordinated notes Dominion Energy 685 5.750% 2054 None Total repayments, repurchases and redemptions $ 2,420 $1,663
RewordedMD&A
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